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Home My WebLink About190-1061.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): Middle Ground Shoal / MGS Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,689'N/A Casing Collapse Structural Conductor Surface 1,130 psi Intermediate Production 3,810 psi Liner 5,410 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size N/A COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018756 190-106 50-733-20420-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC MGS C13A-23 N/A TVD Burst 10,559 & 10,702 6,330 psi 7,240 psi Tubing Size: MD 2,730 psi 370' 1,332' 370' 1,336' 24" 13-3/8" 370' 1,336' 9,830' Perforation Depth MD (ft): 10,780 - 11,550 9,830' See schematic Tubing Grade:Tubing MD (ft): 9,210 - 9,775 Perforation Depth TVD (ft): 9,872' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 5/6/2021 2-7/8" Daniel E. Marlowe See schematic 6.5# / L-80 Other: Oil Safe AR Acid Soak 9,872'11,642'9,840'±3,500 psi 1,277'7" 8,404'9-5/8" 11,689' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:47 am, Mar 16, 2021 321-133 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.03.16 09:50:23 -08'00' Dan Marlowe (1267) SFD 3/16/2021 10-404 Oil Safe AR Acid Soak gls 3/17/21 DSR-3/16/21Comm on Required? Yes 3/17/21 dts 3/17/2021 JLC 3/18/2021 RBDMS HEW 3/18/2021 Well Prognosis Well Name:MGS C13A-23 API Number: 50-733-20420-00-00 Current Status:Gas-Lifted producer Leg:Leg #2 Estimated Start Date:5/6/2021 Rig:N/A Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:190-106 First Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer:Karson Kozub (907) 570-1801 (M) Current Bottom Hole Pressure (top perf): 2,200 psi @ 9565’ TVD 0.23 psi/ft Maximum Expected BHP (Hemlock):2,200 psi @ 9565’ TVD 0.23 psi/ft Maximum Potential Surface Pressure:±3500 psi (treatment pump limit) Brief Well Summary The Middle Ground Shoal C13A-23 is a gas lifted producer. The well has two laterals open. Production has fallen off in the last year due to scale buildup in the liner, verified by wireline tags. This project will stimulate the well in an attempt to remediate suspected carbonate scale buildup. Procedure: 1. MIRU pumping equipment. 2. Pressure test surface lines to ±3,500 psi (treatment pump limit) 3. Pump ±3850 gallons Oilsafe AR (synthetic acid) 4. Displace with ±62 bbls FIW 5. Shut down pump and let for ±72 hours. 6. Rig down pumping equipment 7. Turn over to production Attachments: 1. Well Schematic Current 2. Fluid Flow Diagrams 3. Oilsafe AR – Technical Data Sheet 2 7/8" tubing cap = .0058 bbl/ft 92 bbls _____________________________________________________________________________________ Updated By: JLL 04/24/19 SCHEMATIC Middle Ground Shoal Well: C13A-23 Last Completed: 02/19/2002 PTD: 190-106 API: 50-733-20420-00 Note: Production reported to State under well name C13A-23 Lateral Drilled as: C13A-23LN PTD: 201-213 API: 50-733-20420-60 370 PBTD: 11,642’ TD: 11,689’ 24” RKB: 34.70’ / RKB to MSL: 105’/ MSL to mudline:73’ 7” 3 4 5 6 7 8 9 10 Window 10,616’-10,629’ 13-3/8” 9-5/8” 1 2 5” Estimated TOC @ 8,830’ PBTD: 13,544’ TD: 13,803’ Estimated TOC @ TOL ` XN X XN CASING DETAIL – Parent Bore Size Wt Grade Conn ID Top Bottom 24” Driven Conductor Surf 370’ 13-3/8” 54.5 K-55 BTC 12.615” Surf 1,336’ 9-5/8”43.5 L-80 LTC 8.755” Surf 4,285’ 47 L-80 LTC 8.681” 4,285’ 9,830’ 7”26 L-80 LTC 6.276” 9,337’ 10,412’ 32 P-110 LTC 6.094” 10,412’ 11,689’ CASING DETAIL - Lateral 4-1/2” 12.6 BTC 3.958” 10,629’ 10,664’ 5”17.93 L-80 513 Hydril 4.276” 10,664’ 11,017’ 18 N-80 STL 4.276” 11,017’ 13,513’ 4-1/2” 12.6 BTC 3.958” 13,524’ 13,803’ TUBING DETAIL 2-7/8” 6.5 L-80 8RD EUE 2.441 Surf 10,559’ 2-7/8” 6.5 L-80 8RD EUE 2.441 10,653’ 10,702’ PERFORATION DETAIL –Parent Well Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date Status HK1A 10,780’ 10,810’ 9,210’ 9,234’ 30 4 01/25/1991 HK1B 10,830’ 10,844’ 9,250’ 9,260’ 14 4 01/25/1991 HK1C 10,890’ 10,944’ 9,296’ 9,337’ 54 4 01/25/1991 HK2A 11,008’ 11,040’ 9,385’ 9,408’ 32 4 01/25/1991 HK2B 11,092’ 11,210’ 9,446’ 9,532’ 118 4 01/25/1991 HK2C 11,244’ 11,396’ 9,556’ 9,666’ 152 4 01/25/1991 HK3 11,446’ 11,550’ 9,702’ 9,775’ 104 4 01/25/1991 PERFORATION DETAIL –Lateral (Liner has double penetration across: HK1-HK3 –HK3-HK1) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date Status HK1A-C 10,747’ 11,015’ 9,184’ 9,403’ 268 02/15/2002 Slotted Liner HK2A-C; HK3 11,017’ 11,637’ 9,405’ 9,848’ 620 02/15/2002 Slotted Liner Repeat HK3- HK2 11,903’ 13,125’ 9,895’ 9,901’1,222 02/15/2002 Slotted Liner Repeat HK1 13,301’ 13,424’ 9,896’ 9,893’ 123 02/15/2002 Slotted Liner JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 313’ 313’ 2.312” 4.640” Baker TE-5 SSSV 2 1,861’ 1,850’ GLM #1 3,382’ 3,211’ GLM #2 4,962’ 4,347’ GLM #3 6,289’ 5,313’ GLM #4 7,303’ 6,053’ GLM #5 7,880’ 6,559’ GLM #6 8,361’ 7,020’ GLM #7 8,812’ 7,451’ GLM #8 9,295’ 7,915’ GLM #9 9,776’ 8,356’ GLM #10 10,321’ 8,826’ GLM #11 3 10,488’ 8,967’ 2.310” 3.210” X Nipple 4 10,525’ 3.250” 4.630” Baker EBH Anchor Seal Assembly 10,526’ 8,999’ 3.250” 5.690” Baker SB-3 Perm Packer 10,535’ 3.937” 4.540” Millout Extension 5 10,547’ 9,017’ 2.205” 3.210” XN Nipple 6 10,559’ 9,027’ 2.500” 3.670” WLREG 7 10,607’ 9,067’ 2.125” 5.875” 7” Baker S Hook Hanger Liner Tool 8 10,653’ 9,106’ 7” Baker SB-3 Perm Packer w/ Millout Ext 9 10,692’ 9,138’ 2.205” OTIS XN Nipple 10 10,702’ 9,147’ OTIS Shear Out Sub Fish: 13,606’ – 224’ BHA w/MWD & LWD (Below slotted liner) Reviewed By: Safety Valve & Well Pressures Test Report P.I. Snpr '~ = z ~~~ Comm Pad: MGS_XTO_C_PLATF InspDt: 2/22/2008 °~Inspected by John Crisp Interval InspNo svsJCr~080225134306 Related Insp: Field Name MIDDLE GROUND SHOAL Operator XTO ENERGY INC Operator Rep Barney Phillips Reason 90-Day `~ rc• I __ - __ _ __ _- _ _ _ -- --- ------ -- -- --_ . _ _ _ _ --- -- - - nspector WelZData _~ Pilots ~ SSi~ ~ SSS1f~Shutln Dt~We1l.Type ~ Well Pressures g j Gas Lift Waiver ~ Comments ' .. Well Permit Separ Set Up Test Tes[ Test Date SI Oi1,WAG,GINJ, [nner Outer Tubin ~ - Number Number PS[ PSI Trip Code Code Code GAS.CYCt.F- St Pcr Pcr ucr vo~iN., v.,~in~,. C12-23 1900200 68 ' C13 23 1880990 68 C13A 23 ._~_ 1901060 68 _- -- - C21 23 ; 1890870 68 __.. 37 37 37 ~ 37 0 i...- -- I 0 ; _. P P ~ P P P - P P P P -- - 1-O1L 1-OIL I-OIL - --- -- - - - - -- - - - -- - - -- -- -_- - - - -- - --- __- --- ------- -- ----- - ---- __ ,_ _ __ - __ ~- t C2l 26 1890040 ~ 68 ~ 21 A 23 1910440 68 ! -- ~_..- 0 T - - ---- - P P --... P P __---- 1-OIL ------ 1-OIL -__ --- ! - - - - -.. - _ - - -~ S SSV out for W/L work --- - -- - -- ~ - - --- - - -- -- ~ X C22-26RD ~ 1760650 ' 68 0 ~ ~ P P 1-OlL 1-OlL ~ C22A-26LN 2041820 68 ~ C31-261tD 2041400 68 0 ~ 0 _ --- ~ -- P P P p 1-OIL 1-OIL -- - _- ---- - -- - -- - - _C32-23LW 2020340 68 i _ __ C42-23 ~ 1780240 68 _ _ ----- -~ C43-14 I 1881320 68 0 I 0 ~ 0 - P P --- P P -P - --- P _- 1-0[L-- -1-OIL 1-0IL ~ ---~ _ _ --- ~ -~ -- ~ - -- ----- - - -~ -- - --. -~ L _, -I} ---- _ _ ---- ---~ - ------------j ~ • Comments Performance Pilot numbers listed on wells C12-23 & C13-23 are for the pilots on the sepat•ators. Individual wells are not equiped with pilots on this platform. ~N N4AR ~ 9 2008 ;/ Wells Components Failures Failure Rate ~ `-~ i2 25 0 • Tuesday, February 26, 2008 ' ',1'O ~~N~E R G y October 25, 2001 RECEIVED Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 OCT 7. 6 ;7001 Alaska Oil & Gas Cons. Commission Anchorage Application for Sundry Approval; De-Completion of MGS Well C13A-23, Cook Inlet, Alaska Dear Commissioner Heusser, XTO Energy, Inc. hereby applies for Sundry Approval of its plan to de-complete Middle Ground Shoal Well C13A-23 to allow the sidetracking of that well with lateral C13A- 23LN and re-completion of the two wellbores as a multi-lateral. The Application for Permit to Drill C 13A-23LN is submitted under separate cover. The anticipated commencement date of this work is approximately December 1. The well will be de-completed by killing it with oil-base drilling mud and recovering the existing tubing, leaving the permanent production packer in place. After the lateral branch is drilled and cased, the well will be re-completed as a multi-lateral oil producer using a common tubing string and packer set above the junction of the lateral with the main wellbore. A recent BHP survey was run in this well that indicates the reservoir pressure is 3,450 psi at 9,210'TVD. The maximum anticipated surface pressure would occur if the well should become Completely evacuated with only a column of gas in it. This would result in a maximum surface pressure of 2,437 psi. We therefore request that the BOPE test pressure to be used during this de-completion be 3,000 psi. Pertinent information attached to this application includes the following: 1) Form 10-403 Application for Sundry Approval 2) A copy of the proposed abandonment procedure 3) A schematic showing the current condition of the wellbore If you have any questions or require additional information, please contact me at (915) 620-6718 or Bill Penrose at (907) 258-3446. XTOEnergylnc. · 3000N. Garfield · Suite 175 · Midland, Texas79705 ° (915)682-8873 · Fax: (915)687-0862 Ms. Julie Heusser Page 2 Sincerely, XTO ENERGY, INC. Bobby L. Smith Drilling/Operations Manager enclosures cc: Bill Penrose Doug Marshall Mike Langeler Paul Figel RECEIVED OCT ~ 6 2~I Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ]Abandon [ ]Suspend [ ]Plugging [ ]Time Extension [ ]Perforate [ ] Alter Casing [ ] Repair Well [X] Pull Tubing [ ] Variance [ ] Other [ ] Change Approved Program [ ] Operation Shutdown [ ] Re- Enter Suspended Well [ ] Stimulate 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) XTO ENERGY, INC. [X] Development 105' DF [ ] Exploratory ,, 3. Address [ ] Stratigraphic 7. Unit or Property Name 3000 NORTH GARFIELD,SUlly, MIDLAND, TEXAS 79705 [ ] Service Middle Ground Shoal 4. Location of well at surface ~/,~ ~' "/ 8. Well Number 496' FSL, 1,535' FEL, SEC ~ T8N, R13W, SM C13A-23 At top of productive interval 9. Permit Number V,,/ 2361' FSL, 1185' FWL, SEC 23, T8N, R13W, SM 190-106 At effective depth 10. APl Number .~' 2413' FNL, 1775' FWL, SEC 23, T8N, R13W, SM 50-733-20420 At total depth 11. Field and Pool 2413' FNL, 1800' FWL, SEC 23, T8N, R13W, SM Middle Ground Shoal 12. Present well condition summary ~-i (¢r.¢.~ Total depth: measured 11,698 feet Plugs (measured) None true vertical ,/9,878 feet Effective depth: measured 11,642 feet Junk (measured) None true vertical 9,839 feet Casing Length Size Cemented M D TVD Structural Conductor 265' 24" To surface 370' 370' Surface 1,231' 13-3/8" 600 sx 1,336' 1,332' Intermediate 9,725' 9-5/8" 560 sx 9,830' 8,404' Production 11,584' 7" 1,260 sx 11,689' 9,872' Liner RECEIVED Perforation depth: measured 10,780' - 11,550' (7 intervals) True vertical 9,210'-9,775' (7 intervals) 00T ~ ~; Tubing (size, grade and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd at 10,702' Alaska 0il & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) No SSSV, 7" Baker SB-3 at 10,653' MD 13. Attachments [X] Description of Sumary Proposal [ ] Detailed Operations Program [X] BOP Sketch 14. Estimated date for commencing operation 15. Status of well classification as: l-Dec-01 16. If proposal was verbally approved [X] Oil [ ] Gas [ ] Suspended Name of approver Date Approved Service: Contact Engineer Name/Number: Bill Penrose (907) 258-3446 Prepared By Name/Number: Bill Penrose (907) 258-3446 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Title: Bobby L. Smith, Operations/Drilling Manager Date Commission Use Only Conditions of Approval: Notify Commission so representative may witness '2a(~ ~ ~ T<~O.'~ -V,~%,\ IApproval No. ~,-~."~ Plug integrity __ BOP Test ~ Location Clearance - Mechanical Integrity Test ~ ' ' Subsequent form required 10- ~\ (~ ~'~ // Approv.,.,,or ,ero,,.eoomm,ss,on Oomm,. ,oner Form 10-403 Rev. 06/15/88 Cammy 0ech~li ORIGINAL sate XTO Energy, Inc. mas C 3A-23g Decompletion Procedure Use slickline to pull the orifice valve from the GLM at 10,583', leaving the pocket empty. Move rig over well. Kill well by pumping 8.5 ppg oil-base mud down the tubing, through the open pocket in the GLM at 10,583' and up the annulus. Ensure well is dead. Install BPV, N/D tree, N/U BOPE. Test BOPE to 3,000 psi. [Note: at the discretion of the Drilling Supervisor and AOGCC Inspector (if present), blind rams will be tested after tubing is pulled from hole if there is a chance a gas bubble will settle under BPV, making it difficult or dangerous to release.] Pull BPV. M/U landing joint to tubing hanger, back out lock-down screws and pull hanger just clear of the bowl seat. Release the Baker EBH-22 Tubing Anchor Seal Assy from the SB-3 Permanent Production Packer by rotating the tubing to the right. 12 - 18 rotations to the right (at depth) are required to release the anchor. Ensure well is dead and POH with tubing, checking for NORM while POH. L/D tubing and completion jewelry and send to shore. Proceed with sidetrack procedure to drill C13A-23LN and complete that lateral and the C13A-23 original wellbore together as a multi-lateral. Cross Timbers Operating Company Present Completion MGS C13A-23 Cook Inlet, Alaska Leg 4, Conductor 29 APl No.: 50-733-20420 Spud: Otis "XXO/BXE" SSSV @ 334' 24" Conductor Casing @ 370' Surf Csg: 13 3/8", 54.5 lb, K55. Set @ 1336'. Cmt'd w/600 sx. Prod Csg: 9 5/8", 43.5#, L60. Set @ 4285'. 9 5/8", 47#, L80. Set @ 9830'. Cmt'd w/560 sx. Top of 7" Production liner @ 9,337' Liner Csg: 7", 26~, L80. Set @ 10412'. 7", 32~,P110. Set @ 11689'. Cmt'd w/1260 sx. PBTD: 11642' MD (9840' TVD) TD: 11689' MD ( 9872' TVD) Prepared by: jrs 5113199 Checked by: KB: 105' Water Depth' 73' MSL Tubing: 2-7/8", 6.5#, L80, EUE 8rd Item TVD MI3 Gas Lift Mandrel #1 1908' 1896' Gas Lift Mandrel ~r2 3653' 3420' Gas Lift Mandrel ~r3 5522' 4754' Gas Lift Mandrel ~4 6887' 5746' Gas Lift Mandrel #5 7826' 6508' Gas Lift Mandrel ~6 8394' 7051' Gas Lift Mandrel #7 8927' 7561' Gas Lift Mandrel #8 9436' 8047' Gas Lift Mandrel #9 10009' 8560' Gas Lift Mandrel #10 10583' 9047' Ptro Port 991 12 972 12 957 12 940 12 925 12 910 12 895 12 880 12 865 12 1/4" odfice Otis "XD" Sliding Sleeve @ 10618' BakerEBH-22 Tbg Anchor Seal Assembly @ 10648' Baker "SB-3" Pkr (w/MOE) @ 10653' Otis "XN" Profile Nipple @ 10692' Otis Wireline Re-entry guide @ 10702' HC-HD: HD-HE: HE-HF: HI-HK: HK-HN: HN-HR: HR-HZ: 10780'-10810' MD (9210'-9234' 'I'VD) 10830'-10844' MD (9250'-9260' TVD) 10890'-10944' MD (9296'-9337' TVD) 1100'8-11040' MD (9385'-9408' TVD) 11092'-11210' MD (9446'-9531' TVD) 11244'-11396' MD (9556'-9667' TVD) 11446'-11550' MD (9701'-9775' TVD) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT Unit or Lea~ Name , Field end Pool '~..~" IDa,um Referl~llCe l Oil Gravity IGa$ ~$ravity ~ Final Pre~ure Test Data Pr~u~tion and Test D~ APl ~ ~ Dale Shut-In Shut-In Tool Final PRODUCTION RATES Liquid Wt. of Wt. of Casing Pressure Well Name and No. Number ~ ~ Tested Time Tubing Depth B.H. Obser~d (Bbls. per Day) (Mcfd) ~adient Liquid Gas Pr~sure at ~_ O O Pressure MD Temp. Pr~sure Oil Water Gas Column Column Datum , . , ( her~y~~~{~rtify that the~ ~oing is true and corr~t to the best of my knowl~ge. ~ ~ ;igned Ti/le~[~t>~'~ ~[~~'-~ ~.~' Date ~,~-~ __ ........................... :orm 10412 ~' Subrnil in Duplicale Dear Sir/Madam, ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Reference: SHELL C13A-23 Date: 29 July 1993 RE: Transmittal of Data ECC #: 4784.00 ~ Data: NONE ~~ MIDDLE GROUND SHOAL KENAI, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 O.H. LIS TAPE+LISTER Run # 12 Sent by U.S. MAIL Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 / Attn. Rodney D. Paulson Received w Date: ~/ ~ ANCHORAGE EXPRESS P.O. Box 200503 ANCHORAGE, ALASKA 99520-0503 87907 TO ('907) 5~1.1009 EIN $2.GI29384 'DATE ORDER NO. j~..... SHIP TO ......................................................................................... ~¢4"y"~'""~ ......................... ~'"~ ............................. ...........................................~ .~.o,,..,r~- '' ........... ~._.~.......~.~.~ ................................................... ~o~;~ o, .... ~'ion. QUADRUPLICATE ~" .J May 9, 1991 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT- SUBMISSION OF WELL COMPLETION REPORT AND LOG FOR WELL C13A-23 Enclosed, in duplicate, is the Well Completion Report and Log for Well C13A-23. The spud date for C13A-23 was October 16, 1990 and total depth was achieved on December 16, 1990. The well was completed on April 7, 1991 with the first date of production being April 10, 1991. If you have any questions, please call Ms. Susan Brown-Maunder or Ms. Susan Murnan at (907) 276-2545. Very truly yours, W. F. Simpson Manager Regulatory Affairs WFS/slm Enclosures aogcc/compl ete. doc STATE OF ALASKA 0 ~ I ~1! I N A i ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONE 2. Name of Operator Shell ~este~n E 3. Address 601 ~est 5th Avenue, Suite 800, Anchorage, Alaska 99501 4. Location of well at surface 1533' FEL of Sec. 23, T8N, R13~, A.S.P. At Top Producing Interval 2810' FNL & 4126' FEL of Sec. 23, T8N, R13~, A.S.P. At Total Depth 2810' FNL & 3375' FEL of Sec. 23, T8N, R13N, A.S.P. 5. Elevation in feet (indicate KB, DF, etc.) 105' KB 6. Lease Designation and Serial No. ADL 18756 12. Date Spudded 10-16-90 17. Total Depth (MD+TVD) 11,689' + 9872' 7. Permit Number 8. APl Number so-733-20420 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C13A-23 11. Field and Pool Middle Ground Shoal "G" Pool 13. Date T.D. Reached 12-16-90 18. Plug Back Depth (MD+TVD) 11,642' + 9840' 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 4-7-91 J 73 feet MSL/ 1 19, Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES 0(] NO [] 334 feet MD I N/A 22. Type Electric or Other Logs Run See Attached Loclgin. g Record 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP HOLE SIZE CEMENTING RECORD AMOUNT PULLED 54.5# K-55 N/A. ,I 13-3/8" 9-5/8.'.I ..... 7" 24. 43.5-47# 26 & 32# L-80 L-80,P-I' SETTING DEPTH MD BOTTOM 0' 1336' 0' 9830' 9337' 11,689' ,, Perforations open to Production (MD+TVD of Top and Bottom and interval, sizeandnumber) All 4 J MD 10,780'-10,810' 9210 10,830'-10,844' 9250 10,890'-10,944' 9296 11,008'-11,040' 9385 11,092'-11,210' 9446 11,244'-11,396' 9556 11,446'-11,550' 9701 SPF: TVD -9234' -9260' -9337' -9408' -9531' -9667' -9775' 17-1/2" 12-1/4" 8-1/2" :600sx "G".. + Add. 560sx "G" + Add. 1260sx "G" + Add, 25. TUBING RECORD SIZE DEPTH SET (MD) I PACKER SET (MD) 2-7/8" 10,702' J 10.,_653' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) JAMOUNT& KIND OF MATERIAL USED SEE ATTACHED '"SJTIMULATIONS,,AND REMEDTAL .10 P ERAT I ONS 27. PRODUCTION TEST Date First Production 4-10-91 Date of Test Hours Tested 4-21-91 11 Flow Tubing Press. 85 Casing Pressure 6OO IMethod of Operation (Flowing, gas lift, etc.) Gas L1 ft PRODUCTION FOR IO,L-BBL TESTPERIOD I~ 111.5 CALCULATED !!!~ I OiL'BBL 24-HOUR RATE -'v' J25 GAS-MCF 0 GAS-MCF 0 28. CORE DATA WATER-BBL 7.82 WATER-BBL 17 CHOKE SIZE IGAS-OIL RATIO 2", J , 0 OIL GRAVITY-APl (corr) 35.7 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Submit in duplicate Form 10-407 R~,v 7-1-Rd CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS MEAS. DEPTH ,i TRUE VERT. DEPTH 10,768' ., 9200' t NAME "G" Pool 30, FORMATION TESTS Include interval tested, pressure data, all fluids recovered and Gravity, GOR, and tmle of each phase DaTe 31. LIST OF ATTACHMENTS Daily Report of Operations, Graphic of Well Completion 32 I hereby certify that the foregoing is true and correct to the best of my knowledge ;N:-.,.: .. ~'-'~iened ~ Title __.,,,~- ~' ~ 1~'~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and tog on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fnrm 10-407 MGS C13A-23 WELLBORE DIAGRAM- 4/19/91 () !1 !2 !3 !4 I I !8 I !10 [1 [1 / \ X OTIS "XXO/BXE" SSSV @ 334' 24" Conductor Casing @ 370' 13-3/8" 54.5# K-55 Surface Casing @ 1336' ...... 2-7/8" 6.5# L-80 EUE 8rd Tubing -- X-over 9-5/8" 43.5# to 47# @ 4285' GLM MD TVD PORT Ptro Pso 1 1908' 1896' 12 991 950 2 3653' 3420' 12 972 927 3 5522' 4754' 12 957 904 4 6887' 5746' 16 1015 883 5 7826' 6508' 16 1014 855 6 8394' 7051' 16 1017 833 7 8927' 7561' 20 1120 818 8 9436' 8047' 20 1121 809 9 10009' 8560' 20 1124 799 10 10583' 9047' 5/16" ORIFICE ..... Top of 7" Production Liner @ 9337' 9-5/8" 43.5#/47# L-SO Casing @ 9830' X-over 7" 26# L-80 to 32# P-110 @ 10412' OTIS "XD" Sliding Sleeve @ 10618' BAKER EBH-22 Tbg Anchor Seal Assembly @ 10648' ..... BAKER "SB-3" Pkr. (w/MOE) @ 10653' OTIS "XN" Profile Nipple @ 10692' OTIS Wireline Re-Entry Guide @ 10702' := HC-HD 10780-10810' MD 9210-9234' TVD := HD-HE 10830-10844' 9250-9260' := HE-HF 10890-10944' 9296-9337' := HI-HK 11008-11040' 9385-9408' := HK-HN 11092-11210' 9446-9531' := HN-HR 11244-11396' 9556-9667' := HR-HZ 11446-11550' 9701-9775' I PBTD @ 11642' ~ 7" 32# P-ll0 Production Liner @ 11689' TD @ 11689' WELL NAME: MGS C13A-23 LOCATION: LEG 4, CONDUCTOR 29 COMPLETION DATE: 4/07/91 API NO: 50-733-20420 ELEVATION: 105' KB WATER DEPTH: 73' MSL TD: 11689' MD / 9872' TVD PBTD: 11642' MD / 9840' TVD PRESENT STATUS: PRODUCING LAST TEST: 4/16/91 - 3 BPD GROSS @ 43% CUT, 2 BOPD LOGGING RECORD: DATE COMPANY LOG TYPE 11/08/90 ATLAS 12/13/90 ATLAS 12/14/90 ATLAS 12/26/90 ATLAS INTERVAL LOGGED DIL/SP/GR/CHT 1330' - 9816' DIFL/BHC-AL/GR/SP/CHT 9313' - 11682' ML/CDL/CW/SL/GR/CHT 9800' - 11663' SBT/GR/CCL 9336'- 11610' CASING RECORD: SIZE WEIGHT GRADE TOP BOTTOM CEMENT TOC 24" CONDUCTOR O' 370' 13-3/8" 54.5# K-55 O' 1336' 600 sx 9-5/8" 43.5# L-80 O' 4285' 9-5/8" 47.0# L-80 4285' 9830' 560 sx 7" 26.0# L-80 9337' 10412' 7" 32.0# P-110 10412' 11689' 1260 sx 8830? TOL? GROSS GROSS PERFORATIONS: ZONE MD INTERVAL TVD INTERVAL GUN SIZE JSPF 1/25/91 HC-HD 10780-10810' 9210-9234' 4" VANN 4 1/25/91 HD-HE 10830-10844' 9250-9260' 4" VANN 4 1/25/91 HE-HF 10890-10944' 9296-9337' 4" VANN 4 1/25/91 HI-HK 11008-11040' 9385-9408' 4" VANN 4 1/25/91 HK-HN 11092-11210' 9446-9531' 4" VANN 4 1/25/91 HN-HR 11244-11396' 9556-9667' 4" VANN 4 1/25/91 HR-HZ 11446-11550' 9701-9775' 4" VANN 4 STIMULATIONS AND REMEDIAL OPERATIONS: DATE ZONE DESCRIPTION OF OPERATIONS 2/13/91 HC-HZ 3/31/91 HR-HZ 4/01/91 HN-HR 4/02/91 HK-HN 4/02/91 HI-HK 4/03/91 HC-HF CTU AT w/2500 gals 7.5% HC1 + Matriseal OSR Diverter + 2000 gals 7.5% HC1. AT w/ 2000 gals 7.5% HC1 + 1000 gals 7.5/1.5% HCl/HF AT w/ 2500 gals 7.5% HC1 + 1250 gals 7.5/1.5% HCl/HF AT w/ 2200 gals 7.5% HC1 + 1100 gals 7.5/1.5% HCl/HF AT w/ 500 gals 7.5% HCl + 248 gals 7.5/1.5% HCl/HF AT w/ 2000 gals 7.5% HC1 + 1000 gals 7.5/1.5% HCl/HF DAILY REPORT OF OPERATIONS C13A-23 DRILLING DATE ACTIVITY 10/16/91 TIH W/MUD MOTOR AND BIT #1. ORIENT TOOL FACE W/GYRO DATA TOOL. MUD MOTOR F/375~ T/508~ W/BIT #1. SURVEY AT 30~ INTERVALS W/GYRO DATA. NOTE' THIS REPORT IS ONLY FOR 5 HOURS. RIG WAS ACCEPTED FROM C33-26 AT MIDNITE. 10/17/91 MOTOR/GYRO F/508~ T/762~. EVALUATE SURVEYS. POH T/GET A SURVEY AT BTM. MAKE UP REAMING ASSMY. TIH T/TOP OF MOTOR RUN AT 375~. REAM T/762~. CIRC HOLE CLEAN. RUN GYRO W/DIA-LOG. POH. TIH W/MUD MOTOR ASSMY T/762~. MOTOR/SURVEY F/762~ T/913~ W/BIT #1. 10/18/91 MOTOR/SURVEY F/913~ T/1260~ W/BIT #1. (13.375" CSG POINT) POH. LAY DOWN MOTOR. MAKE UP CLEAN OUT ASSMY. TIH T/762~. REAM OUT MOTOR RUN F/762~ T/1260' W/BIT #1. 10/19/91 CIRC F/SURVEY. RUN GYRO SURVEY ON WIRELINE. POH W/CLEAN OUT ASSMY. TIH W/MUD MOTOR ASSMY. ORIENT MOTOR. DRLG F/1260~ T/1336~ W/BIT #1. POH W/MOTOR. TIH W/REAMING ASSMY. REAM OUT MOTOR RUN F/1260~ T/1336~. RUN GYRO SURVEY TOOLS ON WIRE LINE CIRC/COND F/CSG. POH W/REAMING/CLEANOUT ASSMY. HELD SAFETY/OPERATION MEETING W/CREWS. RIGGED T/RUN CSG. STORM BEGAN MOVING THRU AREA W/HIGH WINDS. SECURED F/CSG RUNNING OPERATIONS TIH W/CLEANOUT ASSMY T/1336~. CIRC/COND ~HILE WAITING FOR WIND T/SUBSIDE. CLEANED PITS, WORKED ON STEAM SYSTEM. WIND LAYED DOWN CONSIDERABLY. POH T/RUN CSG AT RPT TIME. BIT #1COND: 3-2-WT-A-F-I=SD=TD 10/20/91 FINISHED POH T/RUN CSG.5. RAN 1344~ "ON HOOK" OF 13.375" 54.5# K-55 BT&C R-3 CSG. 36 JTS. BAKER PLAIN GUIDE SHOE SET AT 1336~, BAKER FLOAT COLLAR AT 1296~. 6 CENT'S; 10~, 40~ 80~ 120~ 200~ 360~. INSTALLED HOWCO SINGLE PLUG CMT HEAD. RECIP CSG 20~ WHILE CIRC/COND F/CMT. DROP BTM PLUG. LOAD TOP PLUG. PUMPED 5 BBLS OF FRESH WATER. TEST LINES T/3000#. OK. PUMPED 45 BBLS FRESH WATER AHEAD OF 299 SX CLASS ~G~ CMT + 10% GEL + 2% CACL2 + .25% CFR-3. WT 12.8 PPG, 2.08 YIELD. 111BBLS SLURRY. TAILED W/200 SX ~G~ + 2% CACL2 + .25% CFR-3. 15.8PPG, 1.15 YIELD, 41BBLS SLURRY. DROP TOP PLUG. DISPLACED W/206 BBLS FRESH WATER. BUMP PLUG W/1850 PSI. HAD FULL RETURNS THRU OUT JOB. FLOAT HELD. CIP AT 1330 HRS 10/19/90. RIG DOWN. CLEARED FLOOR OF CSG/CEMENTING TOOLS. RIG DOWN , , DW4V2\O30691E. ', DIVERTER LINES, FLOW NIPPLE. PCKD UP 20" STACK, MADE ROUGH CUT ON CSG. LAY DN LDG JT. NIPPLED DOWN 20" STACK. RAN 40~ OF 1" BETWEEN CSG/COND. TAGGED UP SOLID. RIG HOWCO LINES. PUMPED 20 BBLS WATER AHEAD OF 100 SX (16.7 PPG CEMENT F/TOP JOB. GOOD CEMENT RETURNS T/SURFACE. MADE FINAL CUT ON CSG WELD ON 13 5/8" CAMERON "WF" AT RPT TIME. 10/21/91 FINISHED WELD ON 13 5/8" WELL FLANGE. FAILED T/TEST. RE-WELD. TEST TO 800 PSI F/lB MINS. OK. (CHANGED PUMP LINERS/SWABS F/7" T/5.5") #6 GENERATOR WENT BAD. REMOVED IT FROM #7 ENGINE SKID. PULLED COUPLING AND INSTALLED ON SPARE F/ONSHORE. BEGAN INSTALLING GEN, ELECTRICIAN FOUND SPARE GEN TO BE A SERIES WOUND GEN & IS NOT COMPATABLE WITH OUR SHUNT WOUND SYSTEM. NIPPLE UP BOPE. TEST BOPE. ALL OK. INSTALLED WEAR BUSHING. REPLACE SWIVEL PACKING. MAKE UP BHA, TIH W/BIT #2 AT RPT TIME. NOTE: WILL SEND #6 GEN T/TOWN FOR REPAIR/RETURN T/SERVICE. 10/22/91 FINISH TIH. TAGGED CMT AT 1288~. TEST CSG T/1500 PSI F/30 MINS. OK. CLEAN OUT CMT/FLOAT COLLAR/CMT T/1330'. CNG OVER F/WATER T/MUD, DRLG OUT TO SHOE AT 1336' T/1343'. CIRC OUT THICK/CONTAMINATED MUD. DRILLED 1ST FOOT OF HOLE AT 1000 MRS 10/21/90. DID LEAK OFF TEST; 11.9 PPG EMW. (215 PSI W.8.8 PPG MUD) DRLG F/1343' T/1487' W/BIT #2. STARTED LOOSING PUMP PRESSURE. PUMPS OK. PON F/WASHOUT. FOUND ANCHOR PLUG IN ANADRILL MWD WASHED OUT. CNG OUT MWD, TIH. DRLG F/1487~ T/1518~ W/BIT #2RR. DID 5 POINT MWD SURVEY. DRLG F/1518~ T/1831' W/BIT #2RR. POH, LAYED DOWN 2 LC'S, PICKED UP MC AND SHORTEST LC/NEW BIT, TIH. DRLG F/1831' T/1940' W/BIT #3. DID 5 POINT MWD SURVEY. DRLG F/1940' T/2214' W/BIT #3. BIT #2 COND:2-2-WT-A-E-3-RG-BHA 10/23/91 DRLG/SURVEY W/MWD F/2214' T/2374' W/BIT #3. POH. CNG BHA. TIH. DRLG F/2374' T/2447' W/BIT #3RR. DID 5 POINT SURVEY W/MWD. DRLG F/2447' T/2492' W/BIT #3RR. LOST 400 PSI, SURF EQUIP OK. POH, FOUND MANDREL SEAL WASHED OUT OF THE SHOCK SUB. MADE UP NEW BHA, TIH T/SHOE. HAD STARTED INSTALLATION OF GEN #6 WHEN STARTED OUT OF THE HOLE. FINISHED INSTALLATION OF GEN #6. TIH T/2492'. DRLG F/2492' T/2577' W/BIT #3RR. DID 5 PT SURVEY W/MWD. DRLG/SURVEY W/MWD F/2577' T/2948'. BIT #3 COND EACH TIME PULLED: 1-1-A-NO-E-I-NO-(BHA 1ST TIME) 1-1-A-NO-E-I-NO-(WO 2ND TIME) 10/24/91 DRLG/SURVEY W/MWD F/2948' T/3430' W/BIT #3RR. UNIBOLT IN 4" MUD DISCHARGE LINE IN PUMP ROOM BEGAN LEAKING. PULL TO SHOE WHEN FOUND FLANGE FACE WASHED. WELDOR REPLACED UNIBOLT ASSMY W/IOK HAMMER UNION ASSMY. TIH T/3430'. DRLG/SURVEY W/MWD F/3430' T/3844~ W/BIT #3RR CHECK F/FLOW, NONE. POH. CNG ASSMY/BIT. TIH. ON BOTTOM AT ~PT TIME. BIT #3RR COND: 2-3-WT-MH-E-2-ER/RG-BHA DW4V2\O30691E. 10/25/91 DRLG F/3844~ T/3987~ W/BIT #4. DID 5 POINT MWD SURVEY. DRLG/SURVEY W/MWD/BIT #4 F/3987~ T/4890~. 10/26/91 DRLG. W/BIT #4 TO 5042~. REMOVE DELAY VALVE FROM KELLY SPINNER. DRLG. TO 5100~. CIRC. CHECK FLOW, PUMP PILL, AND TOOH FOR MUD MOTOR. PICK UP DRILEX MUD MOTOR, BIT #5, AND TEST MWD. CHANGE OUT KELLY SPINNER. TIH - FILL PIPE @ SHOE. SLIP AND CUT 100~ DRLG. LINE. TIH. 5 POINT SURVEY AND ORIENT MOTOR. DRLG. W/ MOTOR. IADC DULL GRADE BIT #4 - 3-2-BT-M&H-3-I-CT-BHA 10/27/91 MUD MOTOR AND MWD SURVEY FROM 5187~ TO 5487~ SURVEY . CHECK FOR FLOW, PUMP PILL, AND TOOH. (LAY DO~N 24 JTS. S135 DP) 10/28/91 TOOH W/ MUD MOTOR @ 5487~. SAFETY MEETING W/ DRLG. & PRODUCTION CREW. DISCUSS UPCOMING ACID JOB AND CROSSING OF WELL C13-23. PICK UP BHA & TIH TO SHOE. SLIP & CUT 100~ DRLG. LINE. SERVICE RIG. TIH TO 4750~. FILL PIPE & TEST MWD. PICK UP 11JTS. GRADE G DP. REAM MOTOR RUN FROM 5092~ TO 5487~. DRLG. SURVEY. DRLG. IADC DULL GRADE BIT #5 1-1-NO-A-E-I-BHA 10/29/91 DRLG. & SURVEY FROM 6040~ TO 6604~. SURVEY, CHECK FLOW, & PUMP PILL. (TRIPPING FOR BIT AND BOP TEST) NOTE; AT 5283~ TVD C13A-23 CROSSED 41~BELOW C13-23. CLOSE APPROACH WAS @ 6340 MD (5341~TVD) (C13A-23 WELL DEPTH) & WE WERE 18~ FROM C13-23. C13-23 IS BLED TO 0 PSI & IS PRESENTLY SHUT IN. WILL PUT BACK IN PRODUCTION WHEN WE REACH THE FAR SIDE OF CONE OF UNCERTAINTY @ 6677~ MD. 10/30/91 TOOH W/ BIT #6 - TIGHT SPOT @ 5900~ PULL WEAR BUSHING. - TEST BOPS & RELATED EQUIP. - INSTALL WEAR BUSHING MAKE UP BIT. - CHANGE STAB. BLADES - TIH TO SHOE. FILL PIPE & SLIP 150~ DRLG. LINE. TIH TO 4200~ - FILL PIPE & TEST MWD. - TIH TO 6532~. (SET DOWN ON LEDGE) REAM TO BOTTOM. (NO PROBLEMS) DRLG. FROM 6604~ TO 6721~. CHECK SURFACE EQUIP. FOR LOSS OF PUMP PRESSURE. PUMP CARBIDE LAG. TOOH (WET) - FOUND NOZZLE WASHED OUT ON BIT. CHECK NOZZLES ON NEW BIT. - TIH. IADC DULL GRADE BIT #6 3-4-BT-A-4E-I-CT-PR #7 5-4-BT-#1#2#3 M&H-1E-I-CT-WO 10/31/91 TIH. DRLG. AND SURVEY FROM 6721~ TO 7200~. NOTE; BIT #7 WASHED OUT AT THE OUTSIDE JET BETWEEN CONE #~S 1 & 3. NOTE; HOLE TOOK APPROX. 40 BBL. FLUID ON LAST TRIP AND TOOK APPROX. 20 BBL. WHILE DRLG. AT 100 SPM EA. PUMP. SLOW PUMPS TO 95 SPM EA. (NO LOSS) 11/1/90 DRLG. FROM 7200~ TO 7226~. CHECK FLOW - PUMP PILL - TOOH FOR BIT & BHA - LAY DOWN NB STAB. - PICK UP NM SHORT COLLAR - TIH. DRLG. FROM 7226~ TO 7328~. § POINT SURVEY @ 7318~. DRLG. FROM 7328~ TO 7634~. DW4V2\O30691E. 11/2/91 11/3/91 11/4/91 11/5/91 11/6/91 11/7/91 11/8/91 11/9/91 NOTE; TIGHT CONN. @ 7510'. WORK PIPE & BACK REAM. HOLE TOOK APPROX. 60 BBL. ON TRIP. DISPERSED MUD WHILE DRILLING W/ BIT #9 (7250') IADC DULL GRADE BIT #8 - 3-2-CT&BT-I#2-E-I-WT-TQ&BHA DRLG. AND SURVEY FROM 7634' TO 8093' CHECK FLOW, PUMP PILL, TOOH FOR BIT /~ND BHA. - LAY DOWN LEAD COLLAR.- PICK UP WELDED BLADE NB STAB. - CHANGE STAB. SLEEVE ON MIDDLE STAB. PICK UP NEW ,]ARS. IADC DULL GRADE BIT #9 - 6-4-BT-A M&H-F-1/16-CT&WT-TQ&PR TIH TO SHOE. CHANGE LINERS IN MUD PUMPS FROM 5.5" TO 7". REPAIR PULSATION DAMPNER ON PUMP #2. TIH TO 4400'. - FILL PIPE & TEST MWD. TIH - SET DOWN ON BRIDGE @ 7910' PICK UP KELLY AND REAM TO BOTTOM. DRLG. FROM 8093' TO 8189'. 5 POINT SURVEY DRLG. FROM 8189' TO 8370'. DRLG. AND SURVEY FROM 8370' TO 8658'. CHECK FLOW, PUMP PILL, & TOOH. (TIGHT SPOTS @ 8560', 6410', 6300' 6180', & 6045') LAY DOWN MWD & NB STAB. - CHANGE OUT BLADE ON 40' STAB. - PICK UP NEW MWD & BIT. - TIH TO SHOE. CUT DRLG. LINE. TIN & CHECK MWD. DRLG. FROM 8658' TO 8685'. IADC DULL GRADE BIT #10 - 2-1-BT-A(M&H)-E-I-CT-BHA&PR DRLG. AND SURVEY FROM 8685' TO 9138'. DRLG. AND SURVEY FROM 9138' TO 9197'. CIRC. & SURVEY DRLG. AND SURVEY FROM 9197' TO 9228' . CHECK FLOW, PUMP PILL, AND TOOH. (TIGHT SPOTS @ 9189', 9068', 8935' 8548', 6378', & 6284') TEST BOP AND RELATED EQUIP. REAM 30' TO BOTTOM. (10' FILL) DRLG. FROM 9228' TO 9335'. IADC DULL GRADE BIT #11 - 3-3-BT-AM&H-E-I-CT&ER-TQ&BHA 5 POINT SURVEY W/ MWD. DRLG. FROM 9335' TO 9641'. CHECK FLOW, PUMP PILL, AND TOOH FOR BHA. TOOH - (TIGHT SPOTS @ 5930', 6273', & 4625') LAY DOWN MONEL - TIH TO SHOE. REMOVE GUARDS ON DRAWORKS & CHECK BRAKE PADS. - TIGHTEN PADS. - RE- PLACE GUARDS. SLIP DRLG. LINE. TIH REAM TO BOTTOM 40'. - NO FILL. DRLG. & SURVEY FROM 9641', TO 9734'., 5 POINT SURVEY. DRLG AND SURVEY FROM 9734 TO 9830 . SHORT TRIP 10 STDS. - NO PROBLEMS. CIRC. & CONDITION MUD. IADC DULL GRADE BIT #12 - 1-1-NO-A-E-I-BHA NOTE; REACHED TD FOR CASING @ 2340 HRS. 11-07-90. CIRC/COND F/LOGS. CHECKED F/FLOW, NONE. POH. TIGHT SPOTS AT; 8747', 6472' 6380', 5668' AND AT 4331'. (SLM OUT OF HOLE, NO CORRECTION.) RIG U~ WESTERN ATLAS. LOG DIL/SP/GR/CHT. LOGGERS TD WAS 9820'. RIG DH. MAKE UP CLEAN OUT ASSMY AND TIH. NO FILL ON BOTTOM. CIRC/COND F/CSG. CIRC/COND; WOW. HIGH WIND. BIT #13 COND: 3-4-BT-MH-E-I-WT-TD DW4V2\O30691E. 11/10/91 CIRC/COND ON BOTTOM. W.O.W. HIGH WIND. 11/11/91 CIRC/COND ON BTTM. W.O.W. HIGH WIND. FORECAST TO DIMINISH TONIGHT. 11/12/91 CIRC/COND ON BOTTOM. W.O.W. WIND ABATED. CHECK F/FLOW, NONE. PULL UP T/4000'. TIGHT HOLE AT 6030~/5777'. TIH. CIRC/COND HOLE CLEAN F/CASING. POH TO RUN CSG. PULL WEAR BUSHING. CNG RAMS T/9.625". TEST BONNET SEALS T/3000#. OK. HELD PRE-JOB SAFETY AND OPERATIONS MEETING W/DRLG/CRANE/CSG CREWS. RIG TO RUN CSG. RUNNING CSG. AFTER RUNNING 5 BAKER-LOC JTS, MADE THE NEXT 10 JTS UP TO LAST THREAD AND NOTED TORQUE. AVERAGE WAS 8760#. WILL OBTAIN NEW VALUE FOR NEXT WEIGHT PIPE ALSO. BIT #13RR COND: 3-4-BT-MH-E-I-WT-TD 11/13/91 RUNNING 9.625" CSG. DETAILED: USED 10 HOWCO CENTS 80~ APART F/SHOE. JOINTS LENGTH DESCRIPTION 104 135 2 FROM TO 37.83 KB TO CIW "WF" SEAT 0.00 37.83 4220.87 9.625" 43.5# L-80 LTC 37.83 4258.70 5462.25 9.625" 47.0# L-80 LTC 4258.70 9720.95 .92 HOWCO SUPER SEAL FC 9720.95 9721.87 80.73 9.625" 47.0# L-80 LTC 9721.87 9802.60 1.40 HOWCO SUPER SEAL SHOE 9802.60 9804.00 RIGGED HOWCO CMT HEAD/LINES. CIRC/COND W/RIG PUMP FOR CEMENT. HELD SAFETY/OPERATIONS MEETING W/HOWCO/CREW. CEMENTING DETAIL: PUMPED 5 BBLS FRESH WATER. DROP BTM PLUG. TEST LINES T/2500#. OK. PUMP 95 BBLS FRESH WATER. MIX/PUMP 360 SX CLASS G + .4% CFR-3 + 1.5% GEL + .12% HR-7. 93 BBL SLURRY. TAILED W/200 SX G + .5% CFR-3 + .1% HR-7. 41BBL SLURRY. DROP TOP PLUG. HOWCO PUMPED 13 BBLS FRESH WATER BEHIND TO CLEAN LINES. FINISHED DISP W/RIG PUMP. 710 BBLS MUD. BUMPED PLUG. CIP 2130 HRS. FLOATS HELD. HAD GOOD RETURNS THROUGH OUT AT 9 BBL/MIN. LIFT BOPE. SET 306K ON "AW" SLIPS. CUT CSG. INSTALLED AP SPOOL. TEST T/1500# OK. NIPPLING UP BOPE AT RPT TIME. 11/14/91 FINISHED NIPPLE UP BOPE. CNG RAMS T/5". TEST BOPE; 250/3500# ANNULAR, 250/5000# ALL ELSE. CNG PUMP LINERS TO 5.5". INSTALLED WEAR BUSHING. LAYED DOWN 12.25" BHA FROM DERRICK. TEST CSG T/3000# F/30 MINS. FAX ALL TEST RESULTS T/AOGCC PER REQUEST OF MR. LONNIE SMITH. STRAP/PICK UP 8.5" BHA. CNG OUT JARS LAYED DOWN 9 WORN JTS HWDP. RUN "G" 5"DP IN HOLE, POH LAYING DOWN 46 WORN DP. PICKING UP S-135 DP AT RPT TIME. NOTE: DRAINED/FLUSHED KOOMY UNIT/LINES PUT IN NEW FLUID PRIOR T/TEST. CLEANED ALL FILTERS/TRAPS ALSO. 11/15/91 FINISHED PICKING UP DP. FILL DP, CDL 100'. FINISH TIH W/BIT #14. TAG TOP PLUG ON FLOAT COLLAR AT 9721~ DRLG TOP/BTM PLUGS, FLOAT COLLAR, 81' OF HARD CEMENT AND FLOAT SHOE AT 9804~. DRLG FORMATION F/9804~ T/9827'. DID LEAK OFF TEST T/17.0 PPG EMW W/NO LEAK OFF. BLOW DN CHOKE MANIFOLD DRLG F/9827~ T/1007§' W/BIT ~14. DW4V2\O30691E. CHECK F/FLOW, NONE. DROP DUAL SINGLE SHOTS. PULL T/SHOE. RECOVER SS. SLUG PIPE, POH AT RPT TIME. NOTE: DRILLED 1ST FOOT OF HOLE AT 1300 HRS 11/14/90. 11/16/91 SLM OUT OF HOLE. 26' CORRECTION. ALSO CORRECTED CSG SHOE DEPTH TO 9830~ AS WE DRLG FORMATION JUST OUT OF SHOE. THIS SLM AGREES W/SLM PRIOR T/RUNNING CASING; 9830~ IS CSG PT. DECISION MADE T/PLUG BACK. CAN'T HIT TARGETS. MAKE UP 306~ OF 3.5" TBG CEMENTING STINGER ON DRILL PIPE. TIH T/10101~ (CORRECTED TD). CIRC/COND F/CMT PLUG. HELD SAFETY/OPERATIONS MEETING W/HANDS. PUMPED 5 BBLS FRESH WATER. TEST LINES T/2000 PSI. OK. HOWCO UNIT MOTOR DIED. CNG FUEL FILTERS. FIX GOV LINKAGE. PUMPED 25 BBLS FRESH WATER, 130 SX CLASS G CMT + .5% CFR-3 + .35% HR-7 @ 16.7 PPG. 4.0 GAL/SX, 1.02 CF/SX. 23.4 BBLS SLURRY/12.3 BBLS MIX WATER. 1BBL WATER BEHIND. DISP W/170 BBLS 9.8 PPG MUD T/BALANCE. POH 10 STDS. TRY T/REV OUT, COULD NOT. LAYED DOWN 36 JTS DRILL PIPE. POH T/4600~. TRY TO REV OUT; WAS ABLE T/REV OUT DP VOL. POH CLEANING CMT RINGS OUT OF EACH CONN. BIT #14 COND:2-3-BT-H-E-2-RG-BHA 11/17/91 FINISHED POH, CLEANED CMT RINGS F/BTM OF BOXES. LAYED DOWN TBG STINGER. MAKE UP MUD MOTOR/MWD KICK OFF ASSMY, TIH T/9800~. CIRC/COND F/MOTOR RUN. WASH ON IN HOLE, FOUND HARD CEMENT AT 9905~. ORIENT MOTOR. DRLG F/9905~ T/9964~ T/GET OFF PLUG. CHECKED F/FLOW, NONE. POH, LAY DN MOTOR/MWD, MAKE UP ROTARY BHA, TIH AT REPORT TIME. NOTIFIED AOGCC OF PLUG BACK AT 0815 HRS 11/16/90. MR. LONNIE SMITH. BIT #15 COND: 2-2-WT-A-E-I-NO-BHA 11/18/90 FINISHED TIH W/BIT #16. REAM OUT MOTOR RUN F/9905~ T/9964~. DRLG F/9964' T/10071' W/BIT #16. CHECK F/FLOW, NONE. DROP DUAL SINGLE SHOTS. PULL T/SHOE, REC SS. TIH. DRLG F/10071' T/10164' W/BIT #16. CHECK F/FLOW, NONE. DROP DUAL SINGLE SHOTS. PULL T/SHOE, REC SS. POH F/BHA. CNG BHA/BIT. TIH AT REPORT TIME. DRILLED 1ST FOOT OF HOLE AFTER MOTOR RUN AT 0830 HRS 11/17/90. BIT #16 COND:2-2-BT-HM-E-2-RG/WT-BHA 11/19/90 FINISHED TRIP IN HOLE W/BIT #17. DRLG F/10164' T/10272'. CHECK F/FLOW, NONE. DROP DUAL SS. PULL T/SHOE, REC SS. TIH. DRLG F/10272' T/10394'. CHECK F/FLOW, NONE. DROP DUAL SS. PULL T/SHOE, REC SS. TIN. DRLG F/10394' T/10475'. LAST TRIP T/SHOE HAD TIGHT SPOTS AT 10080' AND 10205'; BIT DEPTHS. 11/20/90 CIRC BTMS UP/CLEAN HOLE F/TRIP. CHECK F/FLOW, NONE. DROP DUAL SS SURVEYS. POH F/NEW BIT/BNA. TEST CHOKE MANIFOLD AS POH. DID WEEKLY BOPE TEST. OK. MAKE UP BIT #18, PUT 3 PT ROLLER REAMER IN PLACE OF XO STAB TO REAM DW4V2\O30691E. OUT MOTOR RUN. (9905' TO 9964') LAYED DOWN 18 JTS BAD "G" DRLG PIPE. CUT DRLG LINE 100'. TIH T/10034' BIT DEPTH. REAM/BACK REAM MOTOR RUN W/ROLLER REAMER F/10034' T/10116' BIT DEPTHS. REAMER IS 135~ ABOVE BIT. PICK UP 18 SINGLES, WASH/REAM T/BOTTOM. DRLG F/10475' T/10595' W/BIT #18. BIT #17 COND: 3-4-BT-H/M-E-I-CT-BHA/HR 11/21/90 DRLG F/10595' T/10607' W/BIT #18. CHECK F/FLOW, NONE. DROP SS. PULL T/SHOE. REC SS. TIH. DRLG F/10607' T/10766' W/BIT #18. CHECK F/FLOW, NONE. DROP SS. POH, WORKED TIGHT HOLE AT 10147'-10127', BIT DEPTH. HAD TO ROTATE UP. RECOVERED SURVEYS AT HWDP. LAY DOWN 10 JTS HWDP/1 STEEL DC AND FINISH POH. CNG BHA AT REPORT TIME BIT #18 COND: 5-5-BT-M/H-E-2-CT-BHA/HR 11/22/90 MAKE UP BHA. TIH T/SHOE. (LAYED OUT 3 BAD JTS "G" DRILL PIPE) ELECTRICIAN CHECKED OUT ROTARY MOTOR, GE752. TIH, HAD TO REAM THRU BRIDGES/TIGHT SPOTS AT 9918' AND AT 10672'. DRLG F/10766' T/10866' W/BIT #19. 11/23/90 DRILL 8.5" HOLE W/BIT #19 F/10866' T/10891'. CIRCULATE & CHECK FOR FLOW. DROP TANDEM SS SURVEY INSTRUMENT. POH INTO CSG SHOE. TIGHT @ 10232' & 9936' RETRIEVE SS SURVEY W/WL. TIH T/10891'. N6 FILL OBSERVED. DRILL AHEAD W/BIT #19 F/10891' T/11086'. NO EXCESS FORMATION PRESSURE OBSERVED WHEN DRILLING THE "HE" INTERVAL. CIRCULATE & DROP TANDEM SS SURVEY INSTRUMENT. POH TO CSG. TIGHT @ 10745', 10233' & 10120'. PUMP PILL. R/U W/L & RIH T/RETRIEVE SURVEY @ REPORT TIME. 11/24/90 RETRIEVE SURVEY & POH F/BIT/BHA. P/U BIT #20 BHA & TIH T/10035'. STOP & FILL PIPE @ 4500' & 9800'. WORK TIGHT HOLE W/KELLY @ 10035'. TIH T/11009'. P/U KELLY & REAM F/11009' T/11086'. DRILL W/BIT #20 F/11086' T/11121' WORK TIGHT HOLE & REAM W/KELLY F/J1049' T/11080' DRILL F/11121' T/11151'. WORK TIGHT HOLE & REAM ~/11091' T/11115'. DRILL F/11115' T/11213'. CIRCULATE & DROP TANDEM SS SURVEY. POH F/11213' T/10233'. TIGHT @ 10925', 10912', 10672' & 10233'. ROTARY CLUTCH FAILED DURING UPREAM OF TIGHT SPOT. REPLACE CLUTCH ASHY, MOVE PIPE AS REQUIRED. BIT #19 CONDITION: 5.4.WT.E.2.ER.BHA 11/25/90 REPAIR ROTARY CLUTCH ASMY. UP REAM THROUGH TIGHT SPOT @ 10233'. POH T/SHOE FOR SURVEY RETRIEVAL. TIGHT @ 10125' & 10015'. RETRIEVE SURVEY W/WL @ SHOE. TRIP FOR BHA CHANGE T/BIT #21 ASHY. P/U KELLY & REAM SECTIONS AS REQ. SLIP & CUT 100' OF DRILLING LINE @ SHOE. DRILL 8.5" HOLE W/BIT #21 ASHY. F/11212' T/11290'. ROTARY TRANSMISSION FAILED. LOW GEAR INPUT/OUTPUT GEARS STARTED TO STRIP. CIRCULATE & CONDITION HOLE. PERFORM SHORT TE~M RE?AI~$ ON DW4V2\O30691E. GEARS TO PROVIDE ADEQUATE USE FOR UPREAMING WHILE POH T/SHOE. PREPARE TO POH T/SHOE @ REPORT TIME. BIT #20 CONDITION' 6.7.BT.MH.E.I.ST.BHA 11/26/90 REPAIR ROTARY TRANSMISSION FOR TEMPORARY USE WHILE/POH. C/C MUD.. LOW GEAR INPUT/OUTPUT GEARS IN TRANS. ARE CHIPPED, STRIPPED/DAMAGED. POH TO SHOE. P/U KELLY & UPREAM @ 11190', 11168' - 10800'. GENERAL HOLE CONDITIONS ARE GOOD W/EXCEPTION OF "LEDGES". P/U KELLY & CIRCULATE HOLE IN 9 5/8" CSG @ 2 HRS. S/D & MONITOR WELL. RIG MAINT: SERVICE PRIME MOVERS, MUD PUMPS, KELLY SWIVEL/ROTARY TABLE SEARCH FOR AND LOCATE ROTARY TRANSMISSION FROM MARATHON OIL PLATFORM "SPARK". MOBILIZE & SECURE REPLACEMENT TRANSMISSION. MONITOR WELL. REMOVE/INSTALL ROTARY TRANSMISSION. ALIGNING I/O SHAFTS @ REPORT TIME. 11/27/90 ALIGN I/O SHAFTS OF ROTARY TRANSMISSION. TEST & PREPARE UNIT FOR USE. TIH @ 0930 HRS. P/U KELLY & REAM @ 10840' - 10850'. DRILL 8.5" HOLE W/BIT #21 F/11290' T/11351' DROP TANDEM SS SURVEY. CIRCULATE/CONDITION ~OLE. POH T/CASING. HOLE IN GOOD CONDITION W/SOME TIGHT SPOTS. RETRIEVE SURVEY. TIH T/11351'. LEDGES @ 10480', 10888', 10995' & 11106'. DRILL F/11351' T/11445' @ REPORT TIME. 11/28/90 DRILL W/BIT #21 ASMY F/11445' T/11512'. WORK PIE @ CONNECTIONS AS REQ. CIRCULATE & DROP SURVEY. POH FOR SURVEY RETRIEVAL. PULL TIGHT @ 11270', 11254', 11214' & 11126' PULL TIGHT & UNABLE TO COME UP THROUGH 11113' WORK TIGHT PIPE W/ROTATION & STROKING. P/U TSA PIPE ~RIVE BUSHING AND BEGIN UP REAMING TIGHT SPOT. MOBILIZE DIALOG BACKOFF/SEVERANCE SERVICE CONTINUE TO UP REAM, W/INTERMITTENT PIPE STROKING. REAM UP 28' W/DRIVE BUSHING ASMY (NET PROGRESS). USE OF THE PIPE DRIVE BUSHING INDICATES APPRECIABLE PROGRESS. RECEIVED VARIANCE OF WEEKLY BOPE TEST FROM L. SMITH OF AOGCC. 11/29/90 UP REAM TIGHT SPOT F/11113' T/11085' W/TSA PIPE DRIVE BUSHING. WORK JARS UP, PIPE CAME RELUCTANTLY FREE. POH T/CSG SHOE. TIGHT/lO170' MONITOR WELL, PREPARE RIG FLOOR T/POH. POH W/BIT #21ASMY. L/D 10 JTS HWDP, JARS, ALL NON-MAG COMPONENTS. TEST BOPE: PULL WEAR RING, TEST PIPE RAMS, BLIND RAMS, HCR, STAND PIPE U/L KELLY VALVES, KILL LINE VALVES, FLOOR SAFETY VALVES & CHOKE MANIF. @ 250/5000#. ANNULAR PREVENTER @ 250/3500#. TIME & FUNCTION TEST ACCUMULATOR. RESET BORE PROTECTOR. P/U BIT #22 BHA ASMY. TIH, FILL PIPE @ 4500' & CSG SHOE. BIT # 21COND: 8.8.BT.A.E.3.BT.PR 11/30/90 CONTINUE TIH W/BIT #22 ASMY. P/U KELLY & WASH/REAM F/10132' T/11035'. TIGHT HOLE CONDITIONS EXIST W/LEDGES OR BRIDGES REQUIRING WORK IN THIS INTERVAL. OBSERVE PROGRESSIVE DROP IN PUMP PRESSURE. CHECK ALL SURFACE SYSTEM COMPONENTS. CIRC. & DROP CARBIDE PILL TO MONITOR FOR WASHOUT. NO EARLY ARRIVAL OF CARBIDE SEEN BEFORE FULL CIRCULATION. DW4V2\O30691E. 12/1/90 12/2/90 12/3/90 12/3/90 12/4/90 POH WET TO LOOK FOR WASHOUT. LOCATE WASHOUT 3'+/- BELOW BOX CONN. @ 5934' FROM RKB ON A JOINT OF S-135. L/D SAME. R/U & PUMP THROUGH DP TO CONFIRM INTEGRITY OF DP PRIOR TO TIH. TIH T/CSG SHOE. FILL PIPE AS REQUIRED. CHECK CROWN-O-MATIC OPN. SLIP & CUT 200' OF DRILL LINE. WORK MAINTENANCE ON BRAKE SYSTEM. TIH T/10975'. P/U KELLY @ REAM F/10975' T/11150'. ENCOUNTER SIGNIFICANT "LEDGE" @ 11125'+. REAM W/KELLY F/10975' T/11512', NO FILL OBSERVED. DRILL 8.5" HOLE W/BIT #22 ASMY F/11512' T/11597'. SHORT TRIP 5 STANDS T/11170'. TIGHT @ 11170'. DRILL F/11597' T/11675'. SHORT TRIP 5 STANDS. TIGHT @ 11170'. DRILL F/11675' T/11693' @ REPORT TIME. DRILL W/BIT #22 F/11693' T/11731'. POH F/SHORT TRIP IN PREPARATION FOR WL LOGGING. TIGHT 11400'/9730TVD WORK & CIRCULATE STUCK PIPE @ 11400'. UNABLE TO WORK BHA UP, DOWN OR ROTATE. LOST JAR ACTION IMMEDIATELY. MOBILIZE FISHING OPERATION. RECOVER UP JAR ACTION, LITTLE DN JAR ACTION. JAR W/MINOR PROGRESS. R/U TSA PIPE DRIVE BUSHING FOR ROTATION. UNABLE TO ROTATE. R/D SAME. R/U DIALOG FREE POINT WL IN DERRICK BETWEEN BREAK IN JARRING. RIH W/DIALOG COMPOSITE FREE POINT INDICATOR & STRING SHOT (FP/SS). LOCATE CLEAR FREE POINT @ 11211', BELOW UP-JAR & ABOVE 1JT OF HWDP. WORK 8.25 ROUNDS OF LEFT HAND TORQUE DOWN PIPE. LOCATE & FIRE STRING SHOT @ 11211'. NO OBSERVED BACKOFF. POH W/DIALOG FP/SS. CONFIRM STRING SHOT FIRED. WORK ADDITIONAL LEFT HAND TORQUE IN PIPE. NO MECHANICAL BACKOFF AT SHOT POINT. RETURN RIGHT HAND TORQUE IN PIPE & JAR PIPE WHILE PREPARE #2 SHOT. RIH & LOCATING FREEPOINT @ REPORT TIME. RIH W/DIALOG FP/SS TOOL & LOCATE FREE POINT @ 11211', BELOW UP JAR. WORK 11.5 ROUNDS OF LEFT HAND TORQUE DOWN PIPE. LOCATE TOOL @ FP, FIRE STRING SHOT. NO BACKOFF OBSERVED. POH W/DIALOG, CONFIRM SS FIRED. WORK TORQUE OUT OF PIPE, JAR PIPE WHILE PREPARE SHOT #3. RIH W/DIALOG SHOT #3, LOCATE @ NEXT AVAILABLE HWDP CONNECTION UPHOLE. TIE-IN @ TOP OF HWDP ABOVE UP JARS @ 11161'. WORK 8.5 ROUNDS OF LEFT HAND TORQUE IN PIPE, FIRE SHOT. BACK OFF OBSERVED. POH W/DIALOG. WORK PIPE & PULL FREE OF FISH. TOP OF FISH @ 11161'. 'FISH IN HOLE; SEE FISH BHA DETAIL BELOW. POH W/PIPE T/CSG SHOE. PUMP PILL, SECURE RIG FLOOR FOR POH. POH. RECOVERED 117 STDS OF 5" DP, 12 JTS HWDP, I KEYSEAT WIPER. TIH T/CSG SHOE. L/D 6 JTS BAD PIPE. SLIP & CUT 400' OF DRILL LINE. TIH TO TOP OF FISH @ 11161'. HOLE CONDITIONS TIH WERE GOOD. NO BRIDGES TAG & CIRCULATE OVER TOP OF FISH IN HK SAND. UNABLE TO SCREW INTO TOP OF FISH DUE TO POSSIBLE WASHED OUT AREA. OBSERVE ENGAGING SIDE OF FISH POH W/FISHING ASSEMBLY @ REPORT TIME. POH W/TSA SCREW-IN SUB (SIS) FISHING BHA. SERVICE RIG. P/U & TIH W/TSA SKIRTED SCREW-IN SUB ASMY. TAG LEDGE @ 11008'. DW4V2~O30691E. 12/5/90 12/6/90 P/U KELLY & WORK THROUGH LEDGES T/11049~ (WITHIN 112~ OF TOP OF FISH). UNABLE TO PASS THIS DEPTH (TOP OF HK +/-). POH T/CSG W/SKIRTED SIS ASMY. TIGHT @ 10968~, REAM UP AS REQUIRED. R/D DIALOG WL FROM DERRICK, SECURE RIG FLOOR FOR POH, PUMP PILL. POH W/SSIS FISHING ASMY. L/D SAME. P/U & TIH W/15 JTS OF 3.5" TBG (CMT STINGER) T/11151~ (TOF @ 11161~). CIRCULATE/CONDITION MUD FOR CEMENT SIDE TRACK PLUG @ REPORT TIME. OTHER: RECEIVED VERBAL APPROVAL FROM B. WONDZELL OF AOGCC TO SIDE TRACK WELL. CIRCULATE/CONDITION & PRETREAT MUD FOR CEMENT JOB. HOLD SAFETY & OPERATIONAL MEETING WITH ALL PERSONNEL INVOLVED. PRESSURE TEST ALL LINES @ 250#/4000#. PUMP 100 BBLS FW AHEAD, MIX & PUMP 163.5 BBLS OF CEMENT SLURRY CONSISTING OF 904 SX PREMIUM G CMT, 0.50% CFR-3, 0.2% HR-7, @ 16.7#/gl. 86 BBLS FW (4.0 gal/sk) @ 1.02 cuft/sk. CHASE W/8 BBLS FW. DISPLACE W/178 BBLS OF 10# MUD FOR A BALANCED SIDETRACK PLUG. CIP @ 0730 HRS, 12/04/90. POH 15 STANDS. REVERSE CIRCULATE 1.5 DP VOL. CBU CONVENTIONALLY. POH L/D 3.5" TBG STINGER. R/U & TEST BOPE: TEST ALL HP COMPONENTS @ 250/5000#, ANNULAR PREVENTER @ 250/5000# PER SPM. TIME & FUNCTION TEST ACCUMULATOR SYSTEM. P/U & TIH W/BIT #16RR C/O ASMY T/CSG SHOE. SLIP & CUT 100~ OF DRILL LINE. REPAIR RIG HYDRAULIC HOSE, REFILL SYSTEM & FUNCTION TEST. TIH & TAG TOP OF CEMENT @ 10460~. DRILL TO FIRM CEMENT @ 10500~. CIRCULATE OUT CEMENT CUTTINGS & CONTAMINATED MUD (CBU). PREPARE TO POH @ REPORT TIME. POH T/SHOE. TIGHT @ 10140~ & 10075'. PUMP PILL, POH. L/D SDC. P/U KICKOFF MOTOR ASMY W/BIT #23. TEST MOTOR & MWD. TIH. TIH T/5088~, FILL PIPE & CHECK MWD. MWD SIGNAL DISTORTED. CHECK PUMPS AND REPAIR SWABS ON #1 & #2 MUD PUMPS. RETEST MWD W/NO SIGNAL. POH W/BIT #23 BHA. LOCATE MWD PIPE SCREEN & FIND IT PACKED WITH SCALED CEMENT. CLEAN & CHANGE OUT MWD. CLEAR CEMENT. CHECK MWD/MUD MOTOR. TIH. RABBIT & RATTLE PIPE STANDS WHILE TIH. STOP & CHECK MWD @ 3500~. LOST MWD SIGNAL. POH. RATTLE PIPE WHILE POH. L/D 15 JTS. "G" PIPE. CHECK MUD MOTOR, MWD MUCH SCALED & LAYERED HARD CEMENT SHED FROM INSIDE DRILL PIPE. TIH W/MWD/MOTOR ASMY. RABBIT PIPE WHILE TIH. CHECK MWD @ 3500~. CONTINUE RABBIT PIPE & TIH @ 6800~, REPORT TIME. 12/7/90 12/8/90 FINISHED TRIP IN HOLE T/TOP OF PLUG AT 10500~ ORIENT MUD MOTOR. DRLG W/MUD MOTOR/MWD F/10500~ T/10677~ W/BIT #23 ATTEMPTING TO GET OFF PLUG. CHECK F/FLOW, NONE. POH. CNG BIT AND REPLACED THE 1.5 DEG BENT SUB WITH A 1.75 DEG BENT SUB. ORIENT MWD W/MOTOR. TIH. ORIENT MOTOR. DRLG F/10677~ T/10770~ W/BIT #24. CHECK F/FLOW, NONE. START OUT OF HOLE I:OR BltA/i)IT. DW4V2\O30691E. BIT //23 COND: 4-5-WT-A-E-1-RG-BHA/BIT 12/9/90 FINISHED POH. LAYED DOWN MOTOR ASSMY/MWD. MADE UP ROTARY ASSMY. SLM IN HOLE TO SHOE. CDL 100'. CHANGED BRUSHES/CLEANED DWKS "B" MOTOR. RE-ALINE ROTARY TRANSMISSION; THE HOLD DOWN BOLTS WERE SHEARED OFF. RE-STRUNG SLICK- LINE UNIT'S WIRELINE. FINISHED SLM IN HOLE. MADE 10' CORRECTION. ACTUAL DEPTH WAS 10760'. REAM OUT MOTOR RUN. 10500' T/10760'. DRLG F/10760' T/10878' W/BIT #25. BIT #24 COND: 2-2-WT-A-E-I-NO-BHA 12/10/90 DRLG F/10878' T/10898' W/BIT #25. CHECK F/FLOW, NONE. DROP DUAL SS. PULL T/SHOE. RECOVER SS, TIH. ONE TIGHT SPOT AT 10397'. DRLG F/10898' T/11069' W/BIT #25. CHECK F/FLOW, NONE. DROP DUAL SS. POH. TIGHT SPOTS AT 10280' AND 10088'. RECOVER SS WHEN AT TOP OF HWDP. CHANGING BHA AT RPT TIME. 12/ll/90 v^ ro ON ^v lol20' ur^. our io rs/tro rs. lol20'. 16518', ll02 ' vo lion9'. DRLG F/11069' T/11222' W/BIT #26. CHECKED F/FLOW, NONE. DROP DUAL SS. POH F/CSG SHOE: WORKED TIGHT HOLE AT 10418', 10312', 10219' AND 10190' KELLYED UP AND WORKED OVER TIGHT HOLE 10135' T/10088'. FINISHED POH T/CSG SHOE. RETRIEVE SURVEY TOOLS. TIH, HIT BRIDGE AT 10354'. REAMED OUT BRIDGED/LEDGES AT 10354', 10654'. DRLG F/11222' T/11238' W/BIT #26. BIT #25 COND:4-5-BT-MH-E-1-RG/ER-PR 12/12/90 DRLG F/11238' T/11344' W/BIT #26. CHECK F/FLOW, NONE. DROP DUAL SS. POH. WORKED THRU TIGHT SPOTS BY PULLING INTO THEM 2-3 TIMES, IF DID NOT COME THRU THEN PUT 600 AMPS TORQUE IN STRING WHILE BELOW TIGHT SPOT THEN PULLED THRU WITH STRING TURNING AS IT CAME UP, RELEASING TRAPPED TORQUE AS CAME THRU TIGHT SPOTS. THIS WORKED WELL ENOUGH THAT WE DID NOT HAVE TO KELLY UP OR HIT JARS DURING TRIP OUT. TIGHT SPOTS AT: 10470', 10418', 10323', 10298', 10235', 10113', 10088. LAYED DOWN MONEL BHA, 1 BAD JT HWDP. DID WEEKLY BOPE TESTS. ALL OK. MAKE UP NEW "STEEL" BHA. KEPT SAME "FOOTBALL" STABS. TIH T/SHOE. CDL 100'. TIH T/11264'. HAD TIGHT SPOTS, 10200~, 10350~. DID AS ABOVE METHOD, DID NOT HAVE TO KELLY UP TO WORK PAST LEDGES. WENT IN HOLE FINE. REAM OUT OF GAGE HOLE F/11264' T/11344'. DRLG F/11344' T/11374' W/BIT #27. BIT #26 COND: 8-8-BT/WT-A-E-5-RG-TQ/HR 12/13/90 DRLG F/11374' T/11498' W/BIT #27. CHECK F/FLOW, NONE. POH T/WIPE HOLE, TIGHT SPOTS AT 11208', 11163', 10938', 10470', 10214', 10171', 10088', 10073'. JUST AFTER PULLING THRU THE LAST TIGHT SPOT THE DRAW WORKS "A" TRACTION MOTOR FAILED. PULLED ON INTO CSG W/2 GENS ON "B" MOTOR. (3 STANDS DP) CHANGED OUT TRACTION MOTORS. PREP TO FINISH POH F/NEW BIT AT RPT TIME. DW4V2\O30691E. 12/14/90 POH. CNG BIT. NB STAB 3/16" UG, STRING STAB 3/16" UG, XO STAB 1/8" UG TIH T/BRIDGE AT 10418~. HAD TO ~ELLY UP AND WORK/REAM FROM 10418' TO 10448'. RUN IN HOLE T/11051'. KELLY UP AND WORK/REAM F/11051' T/11230', RUN 2 STDS, REAM 11418 TO 11498'. LAST 80' WAS REAMED BECAUSE BIT/STABS WERE UNDER GAGE. DRLG F/11498' T/11621' W/BIT #28. CHECK F/FLOW, NONE. SHORT TRIP T/SHOE. TIGHT AT 11065', 10200', 10088' COMING OUT AND AT 11065 GOING IN HOLE. DID NOT HAVE TO KELLY UP. DRLG F/11621' T/11634' W/BIT #28. BIT #27 COND: 3-2-BT-M-E-2-RG-HP/HR 12/15/90 DRLG F/11634' T/11698' W/BIT #28. CIRC/COND F/LOGS. CHECK F/FLOW, NONE. POH. TIGHT AT 11028~, 10390', 10214', 10171~ AND AT 10062'. SLM OUT MADE 6' CORRECTION. (WAS 10692', NOW 10698') DID NOT HAVE TO KELLY UP. RIG UP WESTERN ATLAS. LOGGING RUN #1 WAS; DIFL/BHC-AL/GR/SP/CHT. MAX OVER PULL WAS 1000# AT 10418'. LOGGERS TD WAS 10682'. LOGGING RUN #2 IS ML/CDL/CW/SL/GR/CHT. HUNG UP, PULLED LOOSE AT 11566'. LOGGING UP F/11500' OK AT RPT TIME. BIT #28 COND: 2-2-CT(2)-M-E-1-WT-LOG 12/16/90 FINISHED LOGGING RUN #2; ML/CDL/CW/SL/GR/CHT. RIG DOWN W-A. RIG UP DIA-LOG. RAN CSG CALIPER F/9725' T/WELLHEAD. RIG DOWN DIA-LOG. MAKE UP BHA TIH T/SHOE. CDL 100'. FINISHED TI~ T/11698'. HOLE IN GOOD COND. NO TIGHT SPOTS GOING IN. CIRC/COND. CHECK F/FLOW, NONE. POH. HAD ONLY THREE SPOTS W/OVERPULL, 11012', 10980' AND 10949'. BEST TRIP OUT TO DATE. RIG UP W-A. RIH W/FMT/GR/TEMP/CHT AT RPT TIME. 12/17/90 RIH W/FMT/GR/TEMP/CHT. TOOL STUCK AT 10950'. PULLED FREE. POH. RIG DN. TIH W/CLEAN OUT ASSMY. TIGHT AT 10418'. CIRC/COND F/LINER. CHECK F/FLOW, NONE. POH. LAYED DOWN DC/STABS/JARS. RIG T/RUN 7" LINER. HELD SAFETY/OPERATION MEETING W/ALL HANDS. RAN 30 JTS LINER AND 3 FLAG JTS OF 32#, P-110, LTC, 27 JTS 26#, L-80, LTC. PICKED UP BAKER LINER HANGER. REMOVED SHIPPING WRAPPINGS AND FOUND BUTTRESS THREADS. WAIT ON TRANSPORTATION TO GET HANGER T/MACHINE SHOP TO CUT LTC PIN. 12/18/90 WAIT F/TRANSPORTATION FOR LINER HANGER. SENT TO MACHINE SHOP. CUT 8RD LTC PIN. RETURNED IT TO PLATFORM. MADE UP BAKER LINER HANGER, SLM IN HOLE T/9736'. FILLED DP EACH 12 STD DID TORQUE/DRAG TEST. WHILE PUMPING AT 365 GPM HAD A 5000 PSI SPIKE, 1875 STKS HAD BEEN PUMPED. PSI BLED OFF. CONTINUED TO PUMP TO BE SURE CSG WAS CLEAR OF OBSTRUCTIONS. AT 1200 MORE STKS PSI CAME UP T/750 AND HELD. SUSPECTED DP WIPER PLUG INADVERTENLY WENT DOWN HOLE, ENGAGED THE CSG WIPER PLUG AND TOOK IT TO THE LANDING COLLAR. (BBLS STK IS .07) PULLED THE GOOSE NECK FROM SWIVEL, REMOVED KELLY FROM STRING, LOOKED THRU KELLY/"TD" PLUG DROPPING HEAD AND CONFIRMED DP WIPER PLUG WENT. WAIT ON DIA-LOG TO SHOOT HOLES IN LINER SO CAN POH W/LINER. RIG UP DIA-LOG. MADE 2.1125" DRIFT RUN T/9616'. POH. MADE UP 8, 2.1125" CERAM JETS, RIH W/DIA-LOG AT R?T TIME. DW4V2\O30691E. 12/19/90 FINISHED RIH W/DIA-LOG CERAM JETS. SHOT 8 HOLES AT 9610~. POH. RIG DN. CIRC/COND MUD TO POH W/LINER. THINNED MUD TO PRECLUDE SWABING EFFECTS. CHECKED F/FLOW NONE. POH VERY SLOWLY W/LINER. HOLE TAKING PROPER AMT OF MUD. 12/20/90 FINISHED POH, LAYED DOWN 7" LINER. LAY DOWN BAKER PLUG DROPPING HEAD. MAKE UP BHA, TIH T/SHOE. CDL 100~. CIRC/COND MUD AT SHOE. STRAP NEW LINER ONBOARD FROM BOAT. FINISHED TIN. LEDGES AT 10120~ AND 11023~. CIRC/COND F/LINER. 12/21/90 CIRC/CONDITION MUD/HOLE FOR 7" LINER W/CO ASHY. POH T/CSG SHOE. TIGHT @ 11015~ & 10250~. POH W/CO ASHY. R/U CSG CREW, HELD OPERATIONAL & SAFETY MTG W/ALL ACTIVE PERSONNEL. P/U & RIH 7" LINER & JEWELRY PER PROG. R/D CSG CREW. M/U 7" LINER T/TIW HYDRO HANGER & RUNNING TOOL. M/U & RIH ON 5" DP TO 9 5/8" CSG SHOE. STRAP & RABBIT DRILL PIPE @ 2.75" W/RIH T/SHOE. STOP @ SHOE, CIRC THROUGH FLOATS, M/U TIW CEMENTING HEAD T/SINGLE, R/U & TEST HOWCO CEMENT LINE @ 5000# T/RIG FLOOR. RIH W/7" LINER ASHY ON DP, CONTINUE TO RABBIT & STRAP DP. CORRECT TD PER PIPE TALLY -9~, FOR AN ADJUSTED TD OF 11689~ TAG & CONFIRM TD @ 11689~. CASING @ TD, 0430 HRS. R/U & BREAK CIRCULATION ON DOWNSTROKE @ 180 GPM. CIRCULATE/RECIPROCATE LINER 20~ +/- WHILE CONDITIONING MUD/HOLE FOR LINER CEMENT JOB. 12/22/90 CIRCULATE & RECIPROCATE LINER 25~ +/- WHILE COND MUD/HOLE F/CMT JOB. CEMENT LINER: PUMP 5 BBLS FW, S/D & PRESSURE TEST HOWCO LINE @ 5000#, PUMP 45 BBLS FW AHEAD, FOLLOW W/258 BBLS OF CEMENT SLURRY CONSISTING OF 1260 SX PREMIUM G CEMENT, MIXED W/ 0.4% HALAD-344, 0.2% HR7, 0.2% CFR-3 & 150 BBLS OF FW. SLURRY PROPERTIES @ 15.8 ppg, 1.15 cf/sk yld, @ 5.0 gal/sk. UNABLE TO CONTINUE RECIPROCATING WITH 172 BBLS OF SLURRY IN DP. CONTINUE TO PUMP SLURRY WITH LINER ON BTTM. ATTEMPT TO RECIP, NO LUCK. DROP DP WIPER PLUG & CHASE W/lO BBLS OF FW. DISPLACE W/156 BBLS OF DRILL MUD TO BUMP & SHEAR LINER WIPER PLUG. DISPLACE W/88 BBLS TO SET LINER WIPER PLUG. PRESSURE UP TO 3500#. SET HANGER SLIPS, RELEASE LN RUNNING TOOL. PULL OUT OF HANGER ASHY. EST TOL @9336~. CIP 0930 HRS PULL UP 20 STDS & REVERSE CIRCULATE 1.5 DP VOLUME. POH & L/D RT & POB. TEST BOPE PER SPM & AOGCC SPECIFICATIONS. P/U & TIH W/8.5" BIT & 9 5/8" CSG SCRAPER. TAG TOL @ 9337~. NO CEMENT. CBU. POH I STD ABOVE TOL. R/U & TEST LINER TOP @ 3500# FOR 30 mins. GOOD. PUMP PILL, POH, L/D EXCESS DRILL PIPE & HWDP. CHANGE TO & TEST VARIABLE BORE PIPE RAMS FOR 3.5" & 5.0" DP. OTHER: PULLED END OF WELL MUD SAMPLE FOR BIOASSAY ANALYSIS. DW4V2\O30691E. C13A-26 7" LINER DETAIL DESCRIPTION TIW CLS-2 SET SHOE 32# P-110 LTC TIW CF FLOAT COLLAR 32# P-110 LTC TIW HS-SR LNDG CLLR 32# P-110 LTC FROM 11689 11686 11643 11641 11600 11599 32# P-110 LTC FLAG #1 11432 32# P-110 LTC 11411 32# P-110 LTC FLAG #2 11078 32# P-110 LTC 11058 32# P-110 LTC FLAG #3 11891 32# P-110 LTC 10870 26# L-80 LTC 10411 TIW IB-SCR HYDRO HGR 9348 TIW LG-6 SET COLLAR 9345 TO JOINTS 11686 11643 1 11641 11600 1 11599 11432 4 11411 1 11078 8 11058 1 10891 4 10870 1 10411 11 9348 25 9345 9336 SUMMARY: OTHER: 2352~ OVERALL FTG. W/JEWELRY 29 JTS OF 32# P-110 3 FLAG JTS OF 32# P-110 25 JTS OF 26# L-80 - 10 TURBO CENTRALIZERS RUN F/11432~ T/11058~ - 3 TURBO CENTRALIZERS RUN IN LINER LAP SECTION - 20 S/O BAND CENTRALIZERS RUN AS SPECIFIED LTC MAKE-UP TORQUE AVERAGES: 32# @ 4325# NOMINAL, 5406# HIGH, 3243# LOW 26# @ 3840# NOMINAL, 4800# HIGH, 2880# LOW 12/23/90 CHANGE TO VARIABLE BORE PIPE RAMS, TEST @ 250/5000#. RESET WEAR RING. P/U & TIH W/BIT #29, 4.75" DC & 3.5" DP ON TAPERED STRING (SLM), TAG TOC @ 11559~ IN 7" LINER (40~ ABOVE LANDING COLLAR). P/U KELLY, DRILL CMT & WIPER PLUG F/11559~ T/11642~ @ TOP FLOAT COLLAR C & C FOR LOGS. POH 41~, CLOSE PIPE RAMS & TEST CASED HOLE @ 3500# F/30 mins. GOOD. PUMP PILL, POH W/CO ASMY. PULL PITCHER NIPPLE FROM ANNULAR PREVENTER, NIPPLING UP WL LUBRICATOR FLANGE @ REPORT TIME. BIT #29 COND: 4.3.BT.N.I.I.CT.TD 12/24/90 R/U WL LUBRICATOR FLANGE X 7" L-80 RISER TO ANNULAR PREVENTER. R/U ATLAS WL, PREPARE TO RUN SBT/GR/CCL. EXPERIENCE TOOL FAILURE @ SURFACE, MOBILIZE TECHNICIAN FROM BEACH VIA BOAT. R/U & RUN GYRODATA DIRECTIONAL SURVEY F/11627~ T/SURFACE @ WL DEPTH. R/U & SURFACE CALIBRATE SBT/GR/CCL. TEST WL LUBRICATOR @ 1500#. GOOD. LOG SBT/GR/CCL UNDER 1000# CSG PRESSURE F/11610 T/TOL. POH & R/D AWLS. N/D WL LUBRICATOR FLANGE ASMY. NIPPLE DOWN BOPE, PULL DRILLING RISER, SET PRODUCTION TREE. WELL CONTAINS GENERIC MUD #2. 9 5/8" SCRAPER RUN MADE TO TOL. A 7" CSG SCRAPER RUN WILL BE REQUIRED IN CONJUNCTION WITH TIH TO DISPLACE WELL VOLUME W/COMPLETION FLUIDS. RIG RELEASED @ 0500 HRS 12/24/90 TO C22A-26, WO# 263521 DW4V2\O30691E. DAILY REPORT OF OPERATIONS COMPLET I ON C 13A- 23 DATE ACTIVITY 1/22/91 MOVE RIG FROM C22A-26 TO C13A-23. - CHECK WELL FOR PRESS. - N/D XMAS TREE - N/U BOP~S. 1/23/91 FINISH N/U OF BOP - TEST BOP, CHOKE, & RELATED EQUIP. - HYDRIL TO 250/5000 PSI - ALL OTHER 250/5000 PSI. NOTE: 10 OUT 12 VALVES ON CHOKE MANIFOLD WOULD NOT TEST. 1 VALVE ON BOP (CHOKE SIDE) WLD NOT TEST. ALL OF THE ABOVE VALVES HAD TO BE REBUILT. NOTE; DUE TO HEIGHT DIFF. BETWEEN SWEPI & RENTAL BOP, BELL NIPPLE HAD TO BE REBUILT. MAKE UP BHA - SLM IN HOLE W/ SCRAPERS & 3.5" TUBING. REPAIR DRK. LIGHTS. - (DRK. LIGHTS & BAROID SCREEN SHORTED OUT) NOTE; NOTIFIED AOGCC @ 2045 HRS, 1-22-91 OF BOP TEST ON C13A-23. GAVE MSSGE TO ANS. SERV. FAXED WRTN IDENTIFICATION & EXPLANATION OF LATE NOTIFICATION. BHA; BIT, 7" SCRAPER, BS, XO, 25 STDS. 3.5" TUBING, XO, XO, 9.625" SCRAPER, XO, XO : 2331.10~ 1/24/91 SLM IN HOLE W/ SCRAPERS. CUT & SLIP 100~ DRLG. LINE. FINISH TIH TO 11,627~. DISPLACE 10.2 #/GAL. GEN. MUD #2 W/ FIW. (DMPNG ALL RETURNS) TOOH 2 STDS. PAST 9 5/8" CASING SCRAPER. (PIPE CLEAN) - TIH. CIRC. FIW - DUMPING ALL RETURNS. (70 NTU~S OUT) CIRC. FIW THROUGH SUN DRILLING PRODUCTS FILTERING SYSTEM - DUMPING ALL RETURNS. NOTE; AS OF 0500 HRS WELL RETURNS @ 30 NTU. 2100 BBLS. TOTAL PUMPED AS OF 0500 HRS. 1/25/91 REV. CIRC. - FILTER FIW W/ SUN DRLG PRODUCTS - DUMPING RETURNS. 2331 TOTAL BBLS. DUMPED. - CLOSE IN PITS & REV. CIRC. FILTERED FIW. TEST CSG. & LAP TO 3000 PSI W/ 8.5 #/GAL. FLUID. REV. CIRC. - MONITOR GAS (1621 UNITS MAX) CHECK FLOW - NONE SHUT WELL IN & MONITOR BUILD UP. - (8 PSI ) TOOH SERVICE RIG. MAKE UP HOWCO TEST HEAD. SAFETY MEETING - DISCUSS PICKING UP PERF. ASSEMBLY & TRIPPING. PICK UP GUNS & BHA. STRAP & DRIFT 3 1/2" IN HOLE. (FILL 1ST ~7§0~ W/ FLUID. - sl m/C~dw4v2\030691. MONITOR TRIP TANK) NOTE; RECEIVED BOAT W/ 3.5" 13.30 X-95 DRILL PIPE. (APPROX. 170 JTS) 1/26/91 STRAP & DRIFT 3 1/2" TUBING & PERF. ASSEMBLY IN HOLE. RIG UP ATLAS WIRELINE. - RIH TO CORRELATE DEPTH W/ R/A MARKER. - POOH W/ WIRELINE. PICK UP TUBING 34'. (4' DIFF. BETWEEN DRILLER & WIRELINE, DRILLER 4' DEEPER) - M/U TEST HEAD & TEST TO 3500 PSI. SET PACKER PRESSURE UP ANNULUS, VALVE OPENED @ 1250 PSI, GUNS FIRED @ 2650 PSI. 1130 HRS, 1-25-91. FLOW WELL CYCLE OMNI VALVE & REVERSE OUT. FLUID TO SURFACE @ 700 STKS. (49 BBL) STRING CAPACITY 91BBL - CUSHON OF 33 BBL : 58 BBL - FLUID TO SURFACE 49 BBL. = 9 BBL. NOTE; DID NOT APPEAR TO HAVE 9 BBL. OIL CYCLE OMNI VALVE & SHUT WELL IN FOR BUILD UP. UNSEAT PACKER W/ 225,000. (HAD TO PULL 94% OF TUBING TENSILE STRENGTH) REV. CIRC. TO PRODUCTION HEADER 97 BBL. - SWAP TO PITS & CIRC. RIG DOWN TEST HEAD - CHECK FLOW (FLOWING UP TUBING, BUT NOT ANNULUS. WELL OUT OF BALANCE) - PUMP 20 BBL PILL TOOH W/ 3 1/2 TUBING & PERF. ASS. PULL WEAR BUSHING - INSTALL 2 7/8" RAMS - TEST BOP. 1/27/91 PICK UP COMPLETION BHA. - RIH W/ 2 7/8" TUBING (STRAP & DRIFT) - MAKEUP TUBING HANGER & SS CONTROL LINE. R/U SLICKLINE & PULL DUMMY BALL VALVE. - DROP BALL. DRAIN STACK & LAND TUBING. PRESSURE UP TO 2500 PSI TO SET PACKER. - PRESSURE UP TO 3300 PSI TO SHEAR OTIS WIRELINE RE-ENTRY GUIDE. - PICK UP TO 100,000 TO INSURE PACKER SET. R/U SLICKLINE - RIH W/ 2 1/8" DUMMY PERF. GUN TO 10,725' WLM - POOH - RIG DOWN SLICKLINE. SET BVP - N/D BOP'S - CHANGE RAMS TO 3 1/2" - N/U TREE & TEST TO 5000 PSI. - PULL BPV. NOTE; RIG RELEASED FROM C13A-23 TO C43-23 @ MIDIGHT - 1-26-91. COMPLETION DESCRIPTION; OTIS S.S.S.V. - 317.07' GLM #1 - 1927.46' GLM #2 - 3677.91' #3 - 5518.66' #4 - 6915.47' #5 '- 7826.41' #6 - 8422.50' #7 - 8928.86' #8 - 9437.82' #9 - 10,001.00' #10 - 10,585.59' SLIDING SLEEVE 10,618', BAKER TBG. LOCATOR 10,650', BAKER ?KR. 10,654' MILL OUT EXT.10,660', OTIS XN 10,693', OTIS RE-ENTRY SUB 10,704'. sl m/C\dw4v2\030691. 2/13/91 WELL STATUS PRODUCTION TEST COMPLETE, FLUID LEVEL SHOT, AND THE OTIS SAFETY VALVE (SSSV) RETRIEVED AT 315 FT. MOVE RIG FROM C22-A-26 AND SPOT OVER WELL HEAD. RIGGING UP ARTIC RECOIL CTU AND PUMPING EQUIP. RIG UP HOWCO TO MIX PUMP AND RECORD ACID JOB. PRESSURE TEST ARTIC RECOILS BOP STACK TO 5000 PSI. NO LEAKS. PUMPING ACID JOB WITH HOWCO PUMP UNIT. SAFETY MEETING AND JOB PROCEDURES. R.I.H. WITH 1-1/4" COIL TUBING WITH JET WASH NOZZLE AND DOUBLE CHECK VALVE TO 11560 FT. CIRC IN 41.4 BBLS, 7-1/2% HCL ACID TO SPOT ACROSS PERFORATED INTERVAL. (10,780/11,550) 770 FT. CIRC IN THE FIRST STAGE OF ACID AT 5:AM . APPROX 40 GPM AT 3000 PSI. RETURNS TO PRODUCTION SEPERATOR. CSG 575 PSI. TOTAL OF 14 HRS ON TODAYS OPERATIONS. 2/14/91 FINISHED CIRC IN THE FIRST 41.5 BBLS OF 7.5% ACID. ALL ACID PUMPED HAD THE FOLLOWIG ADDITIVES. .5% HAI-85 CORROSION INHIBITOR .2% LOSURF-300 NON-EMULSIFYING AGENT/SURFACTANT 50#/1000 GAL FE-2 IRON CHELATING AGENT (CITRIC ACID) SOAKED FOR 30 MIN. CLOSE FLOW LINE AND BULLHEAD IN 18.1BBLS 7.5% HCL FOLLOWED BY 85.7 BBLS FIW AT ABOUT 20 GPM AT 4700 INJ PSI, THE 1-1/4" X 2-7/8" ANNULUS AVERAGED ABOUT 3600 PSI. CSG PRESSURE STAYED ABOUT 545 PSI THROUGH-OUT JOB. PULL UP HOLE WITH TAIL AT 10,500 FT. ( 280 FT. ABOVE TOP PERFS) AND BULLHEAD IN 30 BBLS FIW. FILTERED THRU ARTIC RECOIL UNIT. PUMPED APPROX 1/4 BBL AT 4800 PSI. RUN BACK IN HOLE TO 11,560 FT. BULLHEAD IN 23.8 BBLS FIW WHILE BLENDING IN 65 GAL MATRISEAL OIL SOLUBLE RESIN. 1/4" BPM. BULLHEAD IN ANOTHER 47.5 BBLS 7.5% HCL FOLLOWED BY 85.7 BBLS FIW. AFTER MATRISEAL HAD REACHED PERFS THE RATE WAS 15 TO 20 GPM AT 5000 INJ PSI.AND 4000 PSI ON 1-1/4" BY 2-7/8" ANNULUS. SPOT 23.8 BBLS XYLENE FLWD BY 17.6 BBLS. FIW TO PLACE XYLENE ACROSS TOP PERFS. PUMPED AND MAINTAINED APPROX 2800 PSI TILL A TOTAL 24 BBLS FIW WAS PUMPED BEHIND SOLVENT. POOH WITH COIL TUBING AND FLUSHED WITH SODA ASH SOLUTION. OPENED UP WELL TO PRODUCTION. RIG OUT ARTIC RECOIL BOPE AND HOWCO. TOTAL OF 19 HRS. RELEASE RIG AT MIDNIGHT. sl m/C\dw4v2\030691. 032891 SKID RIG FROM C22A-26. - SET UP HANDRAILS, COVER HATCHES, SECURE STAIRS, & TIGHTEN STORM CLAMPS. CHECK WELL FOR STATIC CONDITION. - DEAD - SET BPV. - REMOVE FLOW LINE. N/D & PULL TREE. - N/U RISER & BOPE. - FUNCTION TEST BOP. - INSTALL MOUSE HOLE. TEST BOP & RELATED EQUIP. - TEST HYDRIL TO 250/2500 PSI. - TEST BOP & ALL RELATED EQUIP. TO 250/5000 PSI. REMOVE 2-WAY CHECK, BACK OUT LOCKING SCREWS, & ATTEMPT TO PULL TBG. HANGER FROM TYPE F TBG. SPOOL. - STUCK - PICK UP 4 3/4" JARS & (2) 4 3/4" DC~S. JAR TBG. HANGER LOOSE. - LAY DOWN TOOLS. - MAKE UP LAND- ING JT. - ATTEMPT TO RELEASE PACKER ANCHOR. - NO LUCK. R/U DIA-LOG WIRELINE UNIT - RIH W/ CUTTER & SHOOT TBG. BELOW SLIDING SLEEVE @ 10,629~. POOH W/ WIRELINE. - PULL ON TBG. TO INSURE CUT. - TBG. IS CUT. - R/D DIA-LOG. NOTE; FAXED & PHONED AOGCC NOTIFICATION OF UPCOMING BOP TEST. HELD SAFETY MEETING PRIOR TO RIG MOVE. FILLED OUT RIG MOVE CHECKLIST. HOLE TAKING APPROX. 8 BBL/HR. ACCEPTED RIG ON C13A-23 @ 0900 HRS 3-27-91 032991 POOH AND LAY DOWN GAS LIFT VALVES FOR INSPECTION AND SENT THE SLIDING SLEEVE IN TO OTIS FOR INSPECTION. INSTALL WEAR RING. PICK UP TRI-STATE 5-3/4" OVERSHOT WITH HOLLOW MILL EXT, BUMPER SUB, JARS, 12-4-3/4" D.C~S. PUMP OUT, X-OVER AND 3.5" 9.3# EUE AB MODIFIED WORK STRING. T.I.H. FOUND LINER TOP WITH 98 TH. STAND. HAD A VERY LIGHT CHANGE ON WT. INDICATOR. FINISH TRIPPING ON IN TO TOP OF FISH. TRIED TO RO- TATE BUT HAD HIGH (180) AMP READING. EST. TORQUE WAS OVER 4,000 FT.LBS GOT BACK 4 RDS. TRAPPED TORQUE. PULLED KELLY ABOVE TABLE AND TRIED TO ROTATE WITH TUBING POWER TONGS. FOUND THAT 4000 FT. LBS OF TORQUE WOULDN'T ROTATE THE TUBING BUT WOULD ONLY ROTATE IT 2-1/2 ROUNDS. TO MUCH TORQUE FOR TUBING THDS. ORDERED OUT A STRING OF 3.5" 13.3 DRILL PIPE. HOOK LOAD UP 163,000 LBS. HOOK LOAD DOWN 105,000 AND APPROX. 121,000 ROTATING. CIRC AND COND HOLE. HAD A CONTINUOUS 1500 UNITS OF BACKGROUND GAS WHILE CIRC UNTIL MAKING TWO CIRCULATIONS. THEN IT CAME ON DOWN TO APPROX 550 UNITS. HUSKY ARRIVED WITH 3-1/2" DRILL PIPE AT 2:30 AM POOH AND STAND BACK 3-1/2" TUBING WORK STRING. NOTE: HAD A TABLE TOP DRILL AT APPROX 9:AM. DRILLING CREW SECURED WELL AND CHECKED IN AT REC. ROOM. AFTER BRIEFING OF CONDITIONS RETURNED BACK TO WORK. CREW RESPONDED VERY WELL. 033091 FINISH T.O.H. TO FISHING TOOLS. FUNCTON TEST BOP STRAP AND PICK UP 3.5" OD D.P. 95 JTS OF E PIPE FROM L&M RENTAL THE REST X-95 PIPE THAT BELONGS TO SHELL. ALL PIPE IS 13.3 PPF. T.I.H. TO TOP OF FISH. 110629 FT. MILL OVER AND LATCH ONTO FISH. ROTATE 24 TURNS TO RIGHT WITH 10,000 FT. LBS. TORQUE AND WORKED JARS SEVERAL TIMES PULLING UP TO 315,000 HOOK LOAD.( 270,000 STRING LOAD.) COULDN'T PULL FREE. AFTER WORKING FOR 2 HRS WE LOST TORQUE IN D.P. ACTING LIKE WE MIGHT OF STUNG OUT OF PACKER OR GRAPLE TURNED LOSE. INSTALL MORE RACKING FINGERS IN DER. POOH WITH OUT FISH. GRAPLE HAD TURNED LOSE. LAY DOWN OVER SHOT. FUNCTION TEST BOP. PICK UP 1-JT. OF 5-3/4" WASH PIPE WITH 5-7/8" OD MILL SHOE, BOOT BASKET, BUMPER SUB, JARS, AND 12 - 4-3/4" D.C.~S T.I.H. SLIP AND CUT DRILLING LINE. FINISH T.I.H. MILLING OVER "BAKER SB-3 PACKER." AT 10,650. W L M NOTE: HOLE TAKING ABOUT 4.5 TO 5 BBLS. HR. WHILE CIRC. AND ON TRIPS TAKING ABOUT SAME. 033191 FINISH MILLING PACKER AND CHASED DOWN HOLE 30 FT. CIRC BTM. UP AND SPOTTED THE LAST 150 BBLS OF 1MFIW ON BTM. POOH AND LAY DOWN WASH PIPE. MAKE UP TRI-STATE 5-3/4" OVERSHOT DRESSED WITH 2-7/8" GRAPLE. T.I.H. TO 10,650, THEN PICK UP AND SINGLE IN TO 11,530 APPROX 30 FT. ABOVE FISH. KELLY UP AND CIRC BTM. UP THEN SPOT THE LAST 150 BBL OF 1MFIW ON BTM. WORK-OVER AND LATCH ONTO FISH. 11560 FT.(+/-) POOH AND LAY DOWN 53.79 FT. OF FISH. PICK UP 5-7/8" BIT (NO CUTTERS) AND CSG. SCRAPER FOR 7" 32# (6)-4-3/4" D.C.~S AND T.I.H. TO 11630. D.P.M. CIRC 1MFIW FROM 425 BBL RENTAL TK. DOWN TUBING AT 6 BPM. HAVE MUD PITS ALL EMPTY AT START OF CIRC. STARTED SHIPPING TO ONSHORE AT 2 BPM AS SOON AS WE STARTED CIRC. CIRC PRESS. 1440 AT 87 SPM 040191 FINISH CIRC 1MFIW. HAD READING OF 35 NTU TURBIDITY AFTER CIRC DOWN TUBING 850 BBLS. AT 11630 FT.(+/-) WAS ABLE TO CLEAN UP WELL BORE A LOT QUICKER WITH EXTRA TANK FOR FIW, AND EMPTY MUD PITS TO START CIRC. PRODUCTION STARTED EXTRA PUMP TO INCREASE DISCHARGE RATE TO ON-SHORE ALSO PRODUCTION INCREASED 1MFIW TO 3.9 BBLS MIN FOR ABOUT 3 HRS TO US AND WE HAD PLENTY OF WATER. CLEAN OUT TRIP TK. POOH AND LAY DOWN BIT, SCRAPER, BUMPER SUB AND JARS. RIG UP TUBING TONGS AND PICK UP 7" HOWCO MODEL 3L RBP AND 7" RTTS PACKER. T.I.H. WITH 3.5" TUBING WORK STRING TO 11,574 WITH RBP. WITH R.A. PUP JT. 64 FT. ABOVE RTTS. RIG UP ATLAS W.L. AND RAN A GR TOOL FOR CORRELATION OF WORK STRING TO THE SEGMENTED BOND LOG/CCL DATED 12/23/90. FOUND R.A. COLLAR 24 FT HIGH. POOH AND RIG DOWN W.L. RE-SET B.P. AT 11,560 FT. PULL UP AND SET RTTS AT 11,421 FT. RIG UP AND FLUSH HOWCO ACID LINES. PRESSURE TEST TO 8,000 PSI. O:K HAD SAFETY MEETING WITH DRILLING CREW, PRODUCTION CREW, AND HOWCO CREW ESTABLISH INJECTION RATE AT .15 TO .10 BPM AT 3500 PSI. NO COMMUN- ICATIONS ON FIRST SET. MIX UP ACID FOR FIRST BATCH. OPEN CIRC VALVE AT 11417 AND PUMP THE FOLLOWING. A: 47.6 BBLS 7-1/2% HCL PREFLUSH FOLLOWED BY B: 23.8 BBLS 7.5/1.5% HCL/HF MUD ACID FOLLOWED BY C: 27 BBLS 2% CLAYFIX (CLOSE CIRC VALVE) AT 23:05 HR. PUMPED ANOTHER 20.6 BBLS OF CLAYFIX AND CONTINUED PUMPING.AFTER CLOSING VALVE AND PUMPING 2.7 BBLS WE GOT COMMUNICATIONS. HAD TO CLOSE IN BACK SIDE AND HELD 3500 PSI ON ANNULUS. PUMPING IN AT 3300/3450 PSI AT AVG .18 BPM. D: FOLLOW ACID WITH 64 BBLS 1MFIW AT 5:AM WILL TAKE A TOTAL OF 100 BBLS FOR FULL DISPLACEMENT OF ACID. HAD PUMPED IN A TOTAL OF 70 BBLS FIW ON BACK SIDE AT 5'AM, KEEPING BACK SIDE PRESS. UP TO 3500 PSI. 040291 FINISH DISPLACING ACID TREATMENT ON HR-HZ WITH 100 BBLS 1MFIW. SHUT DOWN PUMPS AT 9:AM WITH PRESSURES AS BELOW. USED 103 BBLS ON BACK SIDE TUBING ISIP 3510 PSI @ 9:AM --9:05 3160 PSI-- 9:15 2773 --9:30 2383 CSG. ISIP 3494 PSI @ 9 AM.--9:05 3125 PSI-- 9:15 2755 --9:30 2366 TUBING 10:00 AM 1927 11:00 AM 1344 11:30 AM 1138 CSG 10:00 AM 1917 11:00 AM 1342 11:30 AM 1149 OPENED UP TUBING FOR FLOW BACK AT 11.45 AM AT .25 BPM FLOWED BACK 4.7 BBLS AND PRESSURE WAS TO ZERO. HAD JUST A SMALL STREAM. RETRIEVED BP AND RESET AT 11,435 FT. PULL UP 10 FT. AND SET RTTS. PRESSURE TEST TO 6,000 PSI. TEST OK. PULL UP AND RESET RTTS AT 11,230 FT. PRESSURE TEST LINES. TO 6000 PSI. TOOK INJ. RATE AT .20 BPP FOR 5 BBLS AT 3500 PSI. MIX AND PREPARE TO ACID TREAT THE HN-HR AS FOLLOWS. OPEN CIRC VALVE AT RTTS. PUMPED THE FOLLOWING MIXES 1. 59.5 BBLS 7-1/2% HCL 2. 29.8 BBLS 7-1/2/1.5% HCL/HF 3. 59.5 BBLS 2% CLAYFIX 4. 98 BBLS 1MFIW AFTER PUMPING 7.7 BBLS OF CLAYFIX THE CIRC VLAVE WAS CLOSED THEN THE PUMPING CONTINUED AT 3500 PSI AND APPROX .25 /3 BPM RATE. NO FLOW UP ANNULUS. AFTER PUMPING A TOTAL OF 15 BBLS OF ACID INTO FORMATION WE STARTED GETTING FLOW UP BACK SIDE. CLOSED WELL IN ON TUBING/CASING ANNULUS AND PRESSURED UP BACK SIDE TO 3500 PSI. CONTINUE PUMPING AT 3500 PSI AND .25/.3 BPM. ACID IN PLACE AT 2:02 AM USED 50.4 BBLS 1MFIW ON BACK SIDE. ITSIP 3500 2:02 AM (2:17 AM 2810) (2:32 AM 2500 PSI) (2:47 AM 2200) (3:02 2000 ) ( 3:17 1800 ) (3:32 1600 ) CSG. PRESS STAYED SAME. STARTED FLOWING WELL BACK AT APPROX 1/4 BPM AT 3:45 AM. FLOWED BACK A TOTAL OF 7 BBLS. BACK THEN CONTINUED FLOWING AT ABOUT .2 BPM. CLOSED WELL IN AT 4:30 AM TO GET A PRESSURE B.U. HAD 70 PSI AT 5:AM WILL BLEED PRESS. OFF AND PREPAIR TO RE-SET PACKERS AT 5:AM 040391 WELL CONTINUED TO FLOW BACK UP TUBING. PULL UP AND OPEN CIRC VALVE AT RTTS. CIRC IN 100 BBLS 1MFIW DOWN TUBING THEN CLOSE CIRC VALVE. CHECK FLOW -- OK. RETRIEVE B.P. AND RESET AT 11227 FT. PULL UP AND SET RTTS AT 11,070 FT. RIG UP AND PRESSURE TEST HOWCO LINES TO 5,000 PSI. HAD SAFETY MEETING WITH RIG CREW, PRODUCTION CREW, AND HOWC. TOOK INJECTION RATE. PUMPED IN AT 3200 PSI AT .67 BPM. FOUND WE HAD COMMUNICATIONS. CLOSED IN BACK SIDE AND PRESSURED UP TO 3500 PSI. THEN PUMPED DOWN TUBING INTO FORMATION A TOTAL OF 5 BBLS AT .35 BPM AND 3500 PSI. MIX AND PUMP THE FOLLOWING ACID MIXES INTO THE HK-HN. 1. 52.4 BBLS 7-1/2 % HCL (2)--26.2 BBLS 7-1/2 / 1.5% HCL/HF 3. 52.4 BBLS 2 % CLAYFIX FLUSH (4)--97.2 BBLS 1MFIW AFTER PUMPING 17.4 BBLS CLAYFIX FLUSH,WE CLOSED THE CIRC VALVE, PRESS- URED UP THE BACK SIDE AND CONTINUED PUMPING AT 3500 PSI AT APPROX .25 BPM.THROUGH OUT JOB. FINISHED DISPLACING AT 19:45 HR. ISITP 3463 PSI AFTER 15 MIN. 2833, 30 MIN. 2467, 45 MIN 2173 1 HR. 1945 2 HRS 1158 PSI 2-1/2 HRS 913 PSI OPENED WELL UP AND FLOWED BACK 3 BBLS. UP TUBING AND 2 BBLS UP BACK SIDE. HAVE SMALL STREAM FLOW UP BACK SIDE. LOOKS OK TO RE-SET TOOLS RETRIEVE B.P. FROM 11,227 FT. PULL UP AND RE-SET B.P. AT 11,081 FT. SET RTTS AT 11,049 AND PRESSURE TEST TO 5200 PSI FOR APPROX 5 MIN. TEST OK. MADE STRAIGHT LINE ON CHART. PULL UP AND RE SET RTTS AT 10,987 FT. PRESSURE TEST LINES TO 6500 PSI. OPEN UP AND START INJ. RATE WITH BACK SIDE OPEN. BROUGHT PRESSURE UP TO 3500/3600 THEN SHUT DOWN PUMP. NO COMMUNICATIONS BUT VERY TIGHT EST .05 TO .10 BPM MIX AND PUMP THE FOLLOWING TO TREAT THE HI-HK ZONE. 11.9 BBLS 7-1/2% HCL, 5.9 BBLS 7-1/2/1.5% HCL/HF 11.9 CLAYFIX FLUSH 95.4 BBLS 1MFIW OPEN CIRC VALVE AT RTTS AND PUMP ACID TREATMENT AND 64.85 BBLS FIW CLOSE VALVE AND CONTINUE PUMPING. ABOUT 4 GAL PER MIN. AVG . HAD IN 3.5 BBLS 7-1/2% HCL INTO PERFS AT 5 AM. NO CHANGE. INCREASE PSI TO 4000 PSI AND STILL NO CHANGE. PERFS ? 040491 CONTINUE TREATING HI-HK. AFTER PUMPING A TOTAL OF 6.5 BBLS 7-1/2% HCL INTO PERFS, INCREASE RATE TO .6 BPM AT 38/3900 PSI. ALSO SAW A SLIGHT INCREASE WITH THE HF, BUT SLOWED DOWN WHEN THE CLAYFIX HIT PERFS. ACID IN PLACE AT 8:09 AM ISITP 4245 PSI AFTER 15 MIN 2282 PSI AFTER 30 MIN 1677 PSI AFTER 45 MIN 1316 PSI 1 HR. 1072 PSI 1-1/4 HR. 884 PSI. OPENED UP AND FLOWED BACK APPROX 2.5 BBLS THE HAD ONLY A SMALL STREAM. PREPARE TO TREAT HE-HF PULL UP AND RELEASE RTTS AND T.I. AND RETRIEVE B.P. FROM 11081 FT. RESET B.P. AT 10,990 AND RTTS AT 10,957. PRESSURED UP TO 6800 PSI AND HAD HI PRESSURE LEAK. RESET B.P. AT 10,988 AND RTTS AT 10,954 FT. PRESSURES TESTED PACKERS AGAIN TO 6000 PSI AND HELD GOOD.MADE STRAIGHT LINE ON CHART. PULL UP AND RE-SET RTTS AT 10,864. TRIED TO GET INJECTION RATE AND HAD FLOW UP BACK SIDE. RELEASE TUBING PRESSURE AND PRESSURE UP BACK SIDE AND HAD IMMEDIATE PRESSURE ON TUB. PULL RTTS UP ABOVE ALL PERFS AND SET AT 10,763. PRESSURE UP BACK SIDE TO 3500 PSI. HELD TEST 15 MIN. NO LEAKS. BLEED PRESSURE OFF BACK SIDE AND PUMPED DOWN TUBING FOR INJECTION RATE. OF .12/.14 BPM AT 4455 PSI. PREPARE TO ACID TREAT THE HE-HF, HD-HE, HC-HD. MIX AND PUMP THE FOLLOWING MIXES. 47.6 BBLS 7-1/2% HCL, 23.8 BBLS OF 7.5/1.5 % HCL/HF 47.6 BBLS CLAYFIX FLUSH AFTER PUMPING 47.6 BBLS HCL, 23.8 BBLS HF, AND 21.2 BBLS CLAYFIX THE CIRC VALVE WAS CLOSED AT RTTS. CONTINUED WITH REMAINDER OF 21.2 BBLS CLAY FIX FOLLOWED BY 94.4 BBLS 1MFIW. AFTER FOLLOWING ACID TREATMENT WITH 6 BBLS OF FIW AND PUMPING AT 4200 TO 4500 PSI SOMETHING FAILED IN THE INJECTION STRING. THE TUBING PSI DROPPED TO 100 PSI AND WE GOT APPROX 7 BBLS IMMEDIATELY BACK INTO OUR TRIP TANK. PULL UP ON TUBING AND HAD PROPER WT. CLOSE IN ANNULUS AND PRESSURE UP ON BACK SIDE TO 3500 PSI. NO COMMUNICATION. HELD 3500 ON TUB/CSG ANNULUS AND CONTINUED TREATMENT AT 3500 PSI. IT LOOKS LIKE PACKER FAILED AND THEN RESEATED OR CIRC VALVE. ? AT 5:00 AM HAVE PUMPED 31BBLS WATER AT APPROX 3 BBLS HR. HAVE 62.6 BBLS. MORE FIW TO GO TO HAVE TOTAL DISP. OF ACID. FROM SURFACE TO TOP PERF.IS 94.2 BBLS VOLUME. 040591 CONTINUE TREATING HE-HF, HD-HE, HC-HD AT 3500 PSI. AT 3/3.5 BBLS HR LOWER ANNULUS PRESSURE TO 3000 PSI AND INCREASE TUBING PRESSURE TO 44/4500 PSI. RATE BACK UP TO .13/.14 BPM. FINISH DISPLACING ACID WITH 94.2 BBLS 1MFIW. ACID IN PLACE AT 4:20 PM. ITSIP 4436 PSI 15 MIN 3079 PSI, 30 MIN 2481 PSI, 45 MIN 2087 PSI 1 HR. 1812 PSI, 1-1/4 HRS 1587 PSI. BLEED PRESSURE OFF AT .25 BPM. UNSET RTTS AND REVERSE CIRC. 250 BBLS OF 1MFIW. HAD A LITTLE ACID TO RETURN TO SURFACE. USED ONE SK. OF SODA ASH. CHECKED PH OK/ CIRC BACK 200 BBLS 1MFIW BACK DOWN TUBING. CHECKED FLOW. OK. RIH TO 10988 FT. AND TRY AND RETRIEVE B.P. BUT COULDN'T LATCH ON. PICK UP KELLY AND CIRC ON TOP OF B.P. BUT STILL COULDN'T LATCH ON. POOH LAYING DOWN THE 3.5" 9.3# EUE L-80 WORK STRING. THE CATCHER ON THE RRTS LOOKS OK. CICR VALVE OK. AND ALL BREAKS WERE TIGHT. THE PACKER RUBBERS WERE TORE UP AND A FEW CHUNKS GONE. LAY DOWN HOWCO TOOLS. PULL WEAR RING AND PREPARE TO TEST BOPE AT 5: AM. MANITOWOC REP. (MECHANIC) IS HERE WORKING ON THE BIG CRANE. NOISE AND VIBERATIONS IN TRANSMISSION WHEN YOU POWER DOWN. ONE OF THE SHAFTS TO THE HYDRAULIC PUMPS BAD. SHOULD GET IT FINISHED TODAY. 040691 TEST BOPE. TEST 250/2500 ANNULAR PREVENTER, 250/5000 THE REST OF THE BOPE. HAD TO CHANGE OUT THE LOWER KELLY VALVE, AND THE SAFETY VALVE THATS SCREWED BELOW THE TEST PLUG DUE TO HI-PRESSURE LEAKS. DONE THE ACCUMULATOR PREFORMANCE TEST. OK. PULL TEST PULG AND INSTALL WEAR RING. MAKE UP TRI-STATE 5-3/4" OVER-SHOT DRESSED WITH 1-1/8" CATCH. TIH AND CIRC DOWN OVER B.P. HAD TROUBLE GETTING HOLD OF FISH. COULDN'T GET PROPER DRAG COMING UP. CHASED FISH TO BTM. AND SET MORE WT. ON OVER-SHOT. APPEARED TO HAVE FISH. POOH WET FOR A FEW STANDS. DROPPED BALL TO OPEN CIRC. VALVE. CONTIN- UED PULLING WET FOR 30 MIN THEN PRESSURED UP AND OPENED VALVE. PULL OUT OF HOLE PARTLY WET. LAY DOWN HOWCO R.B.PLUG AND FISHING TOOLS. PULL WEAR RING AND RUN PRODUCTION EQUIP PER PROGNOSIS. 040791 FINISH RUNNING PRODUCTION EQUIPMENT AS FOLLOWS: TUB. HANGER R.T. 35 OTIS SSSV 334 G.L.M. #1 1908 G.L.M. #2 3653 G.L.M. #3 5522 G.L.M. #4 6887 G.L.M. #5 7826 G.L.M. #6 8394 G.L.M. #7 8927 G.L.M. #8 9436 G.L.M. #9 10,009 G.L.M.#10 OTIS X-D SLEEVE BAKER TUB. LOCATOR BAKER "SB-3" PACKER OTIS X-N NIPPLE OTIS SOS HOOK LOAD UP WT. HOOK LOAD UP WT. TO LAND HANGER 10,583 10,618 10,648 10,653 10,692 10,702 95,000 73,000 PRESSURE TO 3000 PSI AND SET PACKER. LET SET ABOUT 10 MIN. PULL UP AND VERIFY PACKER IS SET. OK. PRESSURE BACK UP AND SHEAR OTIS W.L. RE-ENTRY GUIDE, AFTER STTING THE TIE DOWN PINS ON HANGER. SHEARED AT APPROX 3300 PSI. RIG DOWN LINES AND INSTALLED DOUBLE CHECK VALVE IN HANGER. NIPPLE DOWN BOPE, LAY DOWN RISER. INSTALL AND TEST CAMERON 5,000 PSI TREE. BY COOPER OIL TOOL SER REP. ALL OK. PULL DOUBLE CHECK VALVE AND CLOSE IN SWAB VALVE. RIG UP AND PRESSURE TEST SHELL W.L. LUB. TO 1500 PSI. RIH AND PULL DUMMY VALVE AT 334 FT. PUMP THRU 1/4" CONTROL LINE. OK R.I.H. WITH DUMMY PERF. GUN TO 10~750 FOUND RE-ENTRY GUIDE CLEAR. POOH. RIH TO SET OTIS BXE BALL VALVE AT 334 FT. BUT BROKE THE RUNNING TOOL. POOH AND RIG DOWN LUB. AND W.L. UNIT. WILL REPAIR AND SET BALL VALVE AFTER MOVING RIG. RELEASE RIG FROM C13A-23 AT 6'00 PM 04/06/91 A Gyrodata Directional Survey Report For SHELL WESTERN EXPLORATION AND PRODUCTION iNC. LOCATION : PLATFORM FIELD : MIDDLE GROUND SHOAL WELL : CISA - 23 Gyrodata Job Number : ASI290G258 Gyrodata Survey Report Chronology Saturday December 22 12:00 Gyrodata Engineers' T. Stoddard and J.C. Stuart depart Anchorage for Kenai. 12:30 Arrive Kenai. 18:00 Depart from Shell Dock aboard supply boat. 18:30 Arrive Platform" C ". 19:30 Test out equipment. Backup Power Supply found to be faulty. Inform Company Representative and arrange for replacement. Await Survey. SUnday December 23 07:00 Atlas Wireitne experiencing Computer problems. Rig-up Gyrodata equipment prior to running in hole. 08:t5 Power up Gyro - All functions normal. 08:45 Zero tool on surface and Run in Hole. I0:30 Too! at 1t810 Feet. Commence Outrun Survey. 14:45 Re-zero tool on surface. Note wire!ine discrepancy of 17 Feet. 15:00 Break down Gyro and commence survey processing. i8:30 Present Survey to C, Willoughby ( Shell Company' Rep. 19:00 Standby on Platform" C" for next operation. Page A Gyrodata Directional Survey for SHELL WESTERN EXPLORATION & PROD. I NC, PLATFORM 'C' MIDDLE GROUND SHOAL - WELL C13A-23 LOCATION: 4gg FSL & t534 FEL, S£C23, TSN~ R13W, A.S.P, Date Run: 23-DEC-90 t0:42:00 Job Number: AK1290G258 Surveyor: T. STODDARD / J.C.STUART Calculation Method: MINIMUM CURVATURE Survey Latitude: 60.?640deg N Azimuths Corrected 1.3lOOdeg EAST to Grid North Proposed Well Azimuth: 295,8000deg Vertical Section Calculated from Welt Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference Gyrodata SHELL WESTERN EXPLORATION & PROD. INC. PLATFORM 'C' MIDDLE GROUND SHOAL - WELL C13A-23 LOCATION: 499 FSL & 1534 FEL, SEC23, T8N, RIBW, A.S.P. Job Number: AKI290G258 Directional Survey Page MEA$ {NCL AZIMUTH VERT H 0 R ! Z 0 N T A L VERT DOG-LEG DEPTH DEPTH C 0 0 R D I N A T E S SECTION SEVERITY ft deg deg ft feet ft deg/lO0' .0 117.0 217.0 3t7.0 417.0 .00 .00 ,0 ,00 N ,00 E ,0 ,00 All Depths Are Referenced To R.K.B. ,13 272.58 1t7.0 .01N .13 W ,1 .Ii .11 315.55 217.0 .08 N .31 W .3 .09 .3t 216.92 317.0 .07 1.49 228,38 ~I7.0 i.i5 S i.68 ~ 1,0 i.i9 517.0 2.98 257.38 516.9 2.59 S 5. i9 W 3.5 1.82 6t7.0 5.13 248.80 616.7 4.77 S tt.90 W 8.6 2.23 7t7.0 5.92 255.~6 7i6.2 7,6i ~ 2i,07 W i~,6 817.0 4.90 254.9I 815.7 t0.00 S 30.20 W 22.8 1.02 9t7.0 4.02 253.30 915.4 12.12 S 37.68 W 28.7 I017.0 4.26 256.73 i015.2 13.98 S 44.66 W 34.1 .35 ilt7.0 5.88 258.96 Ii14.8 !5.82 S 53.30 ~ 41.I 1.63 i217.0 7.92 263.?4 i2i4.1 i7.55 S 65. i8 W 51.0 2.12 !3i7.0 9.0I 257.48 i3!3.0 20.00 S 79.68 ~ 63.0 t.42 i417.0 8.87 253.27 1411.8 23.92 S 94.70 W 74.9 ,67 1517.0 9.02 253.64 t510.5 28.34 S i09.60 W 86.3 16t7.0 9. t3 253.67 i609.3 32.78 S i24.73 W 98.0 .11 1717.0 9.43 253.60 I708.0 37.32 S 140.20 W !10.0 .3! t8!7.0 9.85 253.75 t806.6 42.03 S t56.28 W 122.4 1917.0 !1.59 257.4I 1904.8 46.61 S 174.31 W 136.6 1.87 20!7.0 t2.97 259.76 2002.5 50.80 S 195.16 W 153.6 1.46 2t17.0 15. t0 262.86 2099.5 54.41 S 2i9.12 W 173.6 2.25 2217.0 t8.41 265.12 2195.3 57.38 S 247.78 W 198.1 3.38 2317.0 22.14 265,06 2289.1 60.34 S 282.30 W 227,9 3.73 24t7,0 24.07 266.11 2381.0 63.35 S 321.42 W 261,8 1.97 Gyrodata SHELL WESTERN EXPLORATION & PROD. INC. PLATFORM 'C' MIDDLE GROUND SHOAL - YELL C13A-23 LOCATION: 499 FSL & 1534 FEL, SEC23, TSN, RI3W, A.$.P. Job Humber: AKI290G258 Directional Survey Page MEAS INCL AZIMUTH VERT H 0 R I Z 0 N T A L VERT DOG-LEG DEPTH DEPTH C 0 0 R D I N A T E S SECTION SEVERITY ft deg deg ft feet ft deg/lO0' 2517.0 25.27 267.06 2471.9 65.82 S 363,08 W 298.2 t,26 2617.0 26.32 267,68 2562,0 67.81 S 406.55 W 336.5 1.08 2717.0 27.81 268.03 2651.0 69.51 S 452.02 W 376.7 !.50 2817.0 29,03 268,75 2738,9 70.84 S 499.59 W 419.0 t,27 2917.0 30.25 269. i7 2825.9 71.74 S 549.04 W 463.1 1,24 30t7.0 3i.76 269,89 29ti.6 72.15 S 600.54 W 509.3 !.55 31t7.0 33.44 270.49 2995.8 71.96 S 654.42 W 557.9 1.72 32i7.0 34.95 271.38 3078.5 71.04 S 710.61 W 608.9 t.58 3317.0 36.62 271.80 3t59.6 69.41 S 769.05 ~ 662.2 1.69 34t7.0 38.20 272.71 3239. i 67,02 S 829.75 W 7t7.9 1.68 35!7.0 39,70 273,71 33t6,8 63.49 S 892,5t W 775.9 !,83 36t7.0 41.i2 273.96 3393,0 59,15 S 957.19 W 836.0 1,43 3717.0 42.52 274.50 3467.5 54.24 S 1023.69 W 898.0 1.45 3817.0 43.90 274.42 3540.4 48,92 S ~091.95 W 961,8 1.38 3917,0 45.i2 275,10 361i.7 43,10 S t16i.81 W t027.2 1.30 40t7.0 44.8i 276.29 3682,4 36.09 S i232, i3 W i093.6 ,90 41!7.0 44.52 277.43 3753.6 27.69 S 1301.92 W 1160.1 .85 4217.0 44.46 277.56 3824.9 18.55 S 1371.39 W 1228.8 .11 43t7.0 45,46 277.42 3895.7 9,33 S t44i,45 W !293,7 i,O0 4417,0 45. i2 277.79 3966.0 .08 N i5tt,90 W t361.2 .43 45i7,0 46.00 277,90 4036,0 9,82 N !582.63 W 1429,! 46i7.0 45.56 278.04 4i05.8 !9.76 N !653.60 4717.0 45.63 278.40 4175.7 29.97 N 1724.3i W 1565.5 .26 4817.0 46.05 278.9t 4245.4 40,77 N t795.23 W t634.0 .56 49t7,0 45.64 279.68 4315.! 52,36 N I866.03 W 1702,8 ,68 Gyrodata SHELL WESTERN EXPLORATION & PROD. INC. PLATFORM 'C' MIDDLE GROUND SHOAL - WELL C13A-29 LOCATION: 499 FSL & 1534 FEL, SEC23, TSN, RI3W, A.S.P. Job Number: AK1290G258 Directional Survey Page MEAS INCL AZIMUTH VERT H 0 R I Z 0 N T A L VERT DOG-LEG DEPTH DEPTH C 0 0 R D I N A T E S SECTION SEVERITY ft deg deg ft feet ft des/lO0' 5017.0 45.69 280.07 4385.0 64.62 N 1936.50 W 1771.6 .28 5117.0 43.65 282.00 4456.t 78.06 N 2005.50 W 1839.6 2.45 5217.0 42.60 288.18 4529.1 95.80 N 2071.44 W 1906.7 4.35 5317.0 42.81 294.91 4602.6 120.68 N 2i34.45 W 1974.2 4.57 5417.0 42.57 300.95 4676.2 t52.40 N 2194.30 W 2041.9 4.10 5517.0 42.1! 305.56 4750. t t89.30 N 2250.60 W 2108.6 3.14 56i7.0 43.00 306.06 4823.7 228.87 N 2305.44 W 2175.2 .95 57t7.0 43.14 307.26 4896.8 269.64 N 2360.23 W 2242.3 .83 5817.0 43.46 307.45 4969.6 311.26 N 2414.74 W 2309.5 5917.0 43.3t 308. tl 5042.3 353.34 N 2469.03 W 2376.7 6017.0 43.60 309.04 5114.8 396,22 N 2522.80 W 2443.8 .70 6117.0 43.65 309.20 5t87.2 439.75 N 2576.32 W 2510.9 .!2 6217.'0 42.80 310.14 5260.1 483.46 N 2629.04 W 2577.4 1.06 6317.0 43.40 3i0.91 5333.1 527.86 N 2680.98 W 2643.5 .80 6417.0 44.00 311.31 5405.4 573.29 N 2733.03 W 2710.1 6517.0 42.76 312.74 5478.1 619.26 N 2784.06 W 2776.i t.58 6617.0 43.89 312.94 5550.8 665.91 N 2834.36 W 2841.7 1.1a 6717.0 43.70 313.89 5623.0 713.47 N 2884.63 W 2907.6 .68 6817.0 43.06 314.35 5695.7 761.28 N 2933.94 W 2972.8 .7t 6917.0 43.74 314.68 5768.4 809.45 N 2982.93 W 3037.9 .72 7017.0 43.06 316.20 584t.0 858.40 N 3031.14 W 3102.6 1.24 7117.0 43.10 316.04 5914.1 907.63 N 3078.48 W 3166.6 .12 7217.0 42.55 316.9I 5987.4 956.91N 3t25.30 W 3230.2 .81 73t7.0 37.15 319.49 6064.2 I004.59 N 3168.04 ~ 3289.5 5.65 7417.0 33. I8 324.39 6145.9 !049.82 N 3203.61 W 3341.2 4.87 Gyrodata SHELL WESTERN EXPLORATION & PROD, INC. PLATFORM 'C' MIDDLE GROUND SHOAL - WELL C13A-23 LOCATION: 499 FSL & 1534 FEL, SEC23, T8N, RI3W, A.S.P. Job Number: AKI290G258 Directional Survey Page MEAS INCL AZIMUTH VERT H 0 R i Z 0 N T A L VERT DOG-LEG DEPTH DEPTH C 0 0 R D I N A T £ S SECTION SEVERITY ft deg deg ft feet ft deg/lO0' 75!7.0 29.38 329.15 6231,4 t093. t4 N 3232,12 W 3385.7 4,55 76t7.0 28.33 327.89 6319,0 1134.29 N 3257.30 W 3426.3 1.19 7717.0 24.80 328.80 6408.4 1172.34 N 3280.79 W 3464.0 3.56 78t7,0 21,64 333,46 6500.3 1206,78 N 3299.90 W 3496.2 3.65 79!7.0 19.26 343.06 6594.0 1239.06 N 3312.95 W 3522.0 4.10 80t7,0 !6,84 348.48 6689.t t269.04 N 3320.65 W 3542.0 2.95 8117.0 15.66 353.10 6785.1 1296.63 N 3325,16 W 3558.0 1.75 8217,0 15.92 355.7t 6881.4 1323.70 N 3327.81 W 3572.2 .76 8317,0 t6.24 357,95 6977,4 t35t,35 N 3329.34 W 3585,6 .70 8417,0 16.52 3.25 7073.4 1379.52 N 3329.03 W 3597,6 1.52 8517.0 17.32 3.9.6 7!89,! 1408.56 N 3327.20 W 3808.6 .82 86t7.0 17.75 5.11 7264.4 1438.59 N 3324.81 ~ 3619.5 .55 8717.0 16.90 13.79 7359.9 14.67.90 N 3319.99 W 3627.9 2.72 88t7.0 16.01 19,46 7455.8 1495.01 N 3311,93 W 3632,5 1.84 8917.0 !5.90 31.25 7552.0 t5t9.73 N 3300,23 W 3632,7 3.24 90t7,0 t5.38 36,52 7648.3 1542. t0 N 3285.23 W 3628.9 1,51 9t17.0 15.08 40.84 7744,8 1562,60 N 3268.83 ~ 3623.1 !.!7 9217.0 17,20 52.65 7840.9 1581.41 N 3248.56 W 3613.0 3.90 9317.0 19.57 56.97 7935.7 1599.51 N 3222.76 W 3597.7 2.73 9417,0 21.38 59.13 8029.4 16t8.00 N 3i93.06 W 3579.0 !,96 95t7.0 23. t0 59,41 8122,0 1637,33 N 3160,53 W 3558.! 1,72 96t7.0 25.42 6t.17 8213.1 1657.66 N 3124.84 W 3534,8 2.44 9717.0 25.78 62.12 8303.3 1678.18 N 3086.81W 3509.5 .54 98t7.0 27.42 63.11 8392.7 1698.77 N 3047.05 W 3482.7 t.70 9917.0 29.64 63.63 8480.6 t720. t6 N 3004.36 ~ 3453.6 2,23 Gyrodata SHELL WESTERN EXPLORATION & PROD. INC. PLATFORM 'C' MIDDLE GROUND SHOAL - WELL C13A-23 LOCATION: 499 FSL ~ 1534 FEL, SEC23, TSN, RI3W, A.S.P. Job Number: AK1290G258 Directional Survey Page 5 MEAS INCL AZIMUTH VERT H 0 R I Z 0 N T A L VERT DOG-LEG DEPTH DEPTH C 0 0 R D I N A T E S SECTION SEVERITY ft deg deg ft feet ft deg/iO0' 10017.0 30.69 63.39 8567.1 I742,58 N 2959.39 W 3422,8 1,05 I01!7.0 31.73 65.59 8652.6 t764.88 N 2912.63 W 3390.4 i,55 10217.0 32.42 68.82 8737,3 1785.43 N 2863.68 W 3355.3 1.85 i0317.0 31.09 70.31 8822.4 1803,81 N 28t4.37 W 3318.9 t,54 10417.0 32.24 72.82 8907.5 t820.39 N 2764.57 W 328i.3 1.75 t05t7,0 33. I8 74.86 8991,6 1835.42 N 2712,67 W 324t.1 t.45 10617.0 32.30 77.12 9075.7 1848.52 N 2660,20 W 3i99.6 !.Si 10717.0 34.79 78.21 9159.1 1860,31N 2606,22 W 3156. i 2.57 10817,0 37.91 79.86 9239.6 1871.55 N 2548.03 W 3108.6 3.27 i0917.0 40.70 80.62 93t7.0 t882,28 N 2485.61 W 3057. t 2.82 11017.0 42.61 82,46 939t,7 1892.04 N 24t9.88 W 3002,1 2,27 lii17.0 43.72 84,10 9464.6 1900,03 N 2351,95 W 2944.5 1,57 11217.0 43,59 85.39 9537.0 1906.36 N 2283.21 W 2885.3 .90 11317.0 43,73 85.67 9609,3 19tl.73 N 2214.38 W 2825.7 .24 it4t7,0 44,48 87,62 968t,I t915,79 N 2i44,91 W 2764.9 1,55 i15t7,0 44.98 88,56 9752.2 !918,i3 N 2074,57 W 2702,6 .83 !16i7.0 46.06 89,48 9822.2 i9t9,35 N 2003,23 W 2638,9 1,26 11627,0 46.17 89.6t 9829.2 1919.41 N 1996.03 W 2632.4 1.48 Final Station Closure: 2769.2 feet 313.8789 degrees PERMIT AOGCC SEPINBLUEUNE LOG INVENTORY log type received "' *rec'date run # comments , ~'?~I?P "" ~. ~. ~ / / ........ HHCISL yes .o ' ' ....... ¢: - , ,, LSS yes no "' S~S yes " ........... '~HDI ' yes no ' ' "CYBER" yes no .......... LOOK .,, , , F~S yes no '~L ~.. yes no ,, , CBL yes CET --yes no "' .... RF[ ~ no GYRO ~ no ' MUD yes no ....... ,, ~ yes no "coRE" yes no ' ' I, , ,,, CORED INTERVALS RECOVERED COMMENTS AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT # ~'~ - i ~ . WELL NAME ~P) ~ ~ ~ { ~ "~ COMPLETION DATE ~. /, ,'] / dtl CO. CONTACT ...... ~~ 'L~~'r' check ~'ff °'r' Fist daia as it"is r~cei .ve~...,*ll.s.t recei¥~d, dpte for 407'. if not re~iuired Ii'st ~s NR ,"Z I ' :r//0i~l,',"' ,',dm., ,~,to~ v' ..... ,,.,~.~1 ,,VI ~,.i'~ tests" O I core deScriP, ti"d ~ cored intCrva~ls core anal~rsis~,¢ dr~, ditch intervals digital data ...................... ~,-7,~" OW ....... LOG 'I'YPE RI~N -' 'iNTERVALS SCALE NO. (to thc nearest foot] _.,[inchllO0'] : : ,, i 11111 ii ii iii i i J ii iii .... ,. iii i i i ii i i lllllUllll i i . L ~1 iiiiiiJl j ij i J IIpl II . . I .~llJ I III II] II] I I J IIIII I I ......... ~ ......... 131 ' · ii i plllll i~iLi ii i ii i ii ii ii Ul i i~111 ii i ii ,lljii i i 14! , , i ~ . _Jii u ..... iii i i _ l.ll i i ii i ii ii i ii il i i . 171 i ii iii i i [j iiiiiii j iiii iii i i ii ii iii iiii iii i · ii illll i i III I I Illl III II I III II III Ill I Ill I [ . I II I I I I I I II II I I RETAIN THIS SECTION FOR YOUR RECORDS ~ [ PRINTS NEG. SEPIA ~--_-~gG;~- Gm ~ L ' PRINTS__~NEG._ !- SEPIA _~_ PRINTS , NEG. ~ SEPIA , , PRINTS ~ NEG ..... SEPIA ~ PRINTS NEG .... SEPIA PRINTS i=~ V ~ ~EPIA ABOVE RECEIVED FROM: ATLAS W~ELINE .... ~ SIGNED ~j ~~~~ Ala~ & Gas Cons. O0i~iosion RE RETAIN THIS SECTION FOR YOUR RECORDS PRINTS ...... NEG .... __~_~__ SEPIA PRINTS ____ NEG ......... SEPIA PRINTS ..... NEG ............ SEPIA PRINTS .... NEG .......... SEPIA PRINTS ____ NEG ....... SEPIA PRINTS ~ NEG .... SEPIA PRINTS __ NEG. ____ SEPIA PRINTS ____ NEG ...... SEPIA ABOVE RECEIVED FROM: ATLAS WIRELINE ATTENTION ~t.~I I[~,,~ /i' SIGNED .../~ N.~~~_. ~. __ DATE RE r-,~ q ,~ _,', '~ ~'-"~ ^-26 ',,..,, ,.~..7 ~~_ /...,~ .~ IND'UCTION --~_~._ SEGMENTED BOND STTLOq · ~HOLE P--~fL E ~j~DE N S ~-~-~ J~.~% DUAL INDUCTION !.~ ~ SPECTRALOG ~,~ EPILOG ABOVE'RECEIVED FROM: ATLAS WlRELIlNE /31~~' ~ORMATION TESTER ATTENTION, ,, v SIGNED .~M~v ~ ~ PRINTS __ PRINTS _____ PRINTS ___ PRINTS PRINTS __ __ PRINTS ~ PRINTS . PRINTS NEG ....... SEPIA NEG ........ SEPIA NEG ............ SEPIA NEG .... NEG .... NEG ..... NEG .... NEG. __ ...... SEPIA ..... SEPIA SEPIA SEPIA ___ SEPIA DATE 19__ August 3, 1990 Telecopy: (907)276-7542 Mr. l~ayne F. Simpson Division Operations ~{anager Shell Western E&P Inc. 601 W. Fifth Avenue, Suite 810 Anchorage, Alaska 99501-2257 Re: Middle Ground Shoal C13A-23 Shell' Western E&P Inc. Permit No. 90-106 Sur. Loc. Platform "C", Leg 4, Conductor 29 Btmhole Loc. 2810'FNL, 3375'FEL, Sec. 23, TSN, R13W, SM. Dear Mr. Simpson~ Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Very truly Yours x:? ,( ,' .> ~_ ~ /~,-~ ~ ~. .; / . '~,, ~,...~ ~. .-%, Lonnie C/.. Smith Co~tssioner of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMR4ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux STEVE COWPER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 Telecopy No. (907) 276-7542 August 1, 1990 ADMINISTRATIVE APPROVAL N O. 44.44 Re: The application of SHELL WESTERN E & P, INC. to drill, complete, and produce the Middle Ground Shoal 18756 No. C-13A-23 well in the Middle Ground Shoal Field. W. F. Simpson Manager, Regulatory Affairs Alaska Division Shell Western E & P, Inc. 601 West Fifth Avenue, Suite 800 Anchorage, Alaska 99501 Dear Mr. Simpson: The referenced application was received on July 27, 1990. The Middle Ground Shoal No. C-13A-23 well is in the steeply dipping West Flank part of the field which requires closer than 80 acre areal well spacing to adequately drain this part of the reservoir. The Alaska Oil and Gas Conservation Commission has studied the evidence available and hereby authorizes the drilling, com- pletion, and production of the referenced well pursuant to Rule 6 of Conservation Order 44. Sincerely, ~on~ie C~ Comm-[ss±oner BY ORDER OF THE COMMISSION dlf/3.AA44 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 July 25, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, A1 aska 99501 Gentlemen' SUBJECT' SUBMISSION OF THE APPLICATION FOR PERMIT TO DRILL MIDDLE GROUND SHOAL WELL NO. C13A-23 Enclosed in triplicate is the Application for Permit to Drill the next well at Middle Ground Shoal, well no. C13A-23. The surface location is Platform C, Leg 4, Conductor 29. Conductor 29 was previously used for the C33-26 well, which was abandoned in October 1982. C13A-23 is currently scheduled to spud on September 5, 1990 following well slot recovery operations. Drilling operations are expected to continue for approximately two and one half months. In the unlikely event that H2S is encountered, we intend to comply with 20 AAC 25.065 and follow the "Recommended Practices for Conducting Oil and Gas Production Operations Involving Hydrogen Sulfide." Please note that C13A-23 is the fourth producer in the governmental quarter section. SWEPI requests a variance by way of Administrative Approval (Rule 6), from Rule I of Conservation Order #44. The current well plan calls for a TVD of 10,039', but SWEPI would like to maintain the flexibility to drill to a maximum prognosed TVD of 10,500'. If you have any questions regarding this report, please contact Susan Brown-Maunder at (907) 263-9613. Very Truly Yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [X] Redri[[ [ ] I lb. Type of we[[. Exploratory [ ] Stratigraphic Test [ ] Development Oil [X] Re-entry [ ] Deepen [ ]I Service [ ] Development Gas [ ] Single Zone [ ] Multiple Zone [ ] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool SHELL WESTERN E&P, INC. 105' KB feet Middle Ground Shoal 3. Address 6. Property Designation E, F, & G Pool 601 West Fifth Avenue, Suite 800, Anchorage, AK 99501 ADL 18756 4. Location of we[[ at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) Platform C, Leg 4, Conductor 29. 499' FSL & 1534 FEL of Middle Ground Shoal Blanket Sec. 23, TSN, R13W, A.S.P. At top of productive interval 8. Well number Number 2810' FNL & 4126' FEL of Sec. 23, T8N, R13W, A.S.P. C13A-23 400 HM7522 At total depth 9. Approximate spud date Amount 2810' FNL & 3375' FEL of Sec. 23, TSN, R13W, A.S.P. September 5, 1990 $200,000.00 12. Distance to nearest property113. Distance to nearest 14. Number of acres in property 15. Proposed depth (MD and TVD) line 2720' to NE corner Sec. 271 well 675' to C22-23 3746 11758' + 10039' ~16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 375 feet Maximum hole angle 42.1 ° Maximum surface 2118 psig At total depth, (TVD) 5732 psig 18. Casing Program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 17-1/2" 13-3/8" 54.5 K-55 BTC 1102 0 0 1102 1100 399 sx "G" + additives 12-1/4" 9-5/8" 43.5 L-80 LTC 4381 0 0 4381 4000 560 sx "G" + additives 47.0 L-80 LTC 5325 4381 4000 9706 8425 8-1/2" 7" 26.0 L'80 LTC 930 9406 8144 10336 8972 809 sx "G" additives 32.0 P-110 LTC 1422 10336 8972 11758 10039 19. To be completed for Redri[[, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth , V~rt._i~a~ ~e.p_th~ Structural .~,~r Conductor Surface intermediate Liner Perforation depth: measured true vertical 20. Attachments Filing fee [X] Property plat [X] BOP Sketch [X] Diverter Sketch [X] Drilling program [X] Drilling fluid program [X] Time vs depth plot [ ] Refraction analysis [ ] Seabed report [ ] 20 AAC 25.050 requirements [ ] !21. I hereby certify that the foregoing is true and correct to the best of my know[edge Signed_ ~ Title Manager Alaska Operations Date 07/25/90 Commission Use Only I08-£0 /90 J seecover tatter Permit Number API number Approvakdate3 ?(~)- /<~ 50' ~_ ~__,<:~)~/~.<:~) for other requirements Conditions of approval Samples required [ ] Yes ~ No Mud log required [ ] Yes '~ No Hydrogen sulfide measures [ ] Yes ~ No Dfrectfona[ survey requfred~l~Yes [ ] No by order of Approved by Commissioner the commission Date<~'-~'~-~ Form 10-401 Rev. ~'-1-85 ~ \072590 Submit in triplicate MIDDLE WELL LOCATION PLAT GROUND SHOAL FIELD COOK INLET, ALASKA WELL: C13A-23 LEASE NO.: ADL18756 -I PLATFORN C LEG NO. 1 LAT.60' 45' 50.163' LONG.151' 30' 08.469' I C32-23 C12-23 23 ~I-I4D C42-23 -8314 C43-23 C41-23 PROPOSED LOCATION AT TOP OF OBJECTIVE: 2810 IT. FROM N LINE AND 4126 FT. FROM SECTION 23, T 8 N, R 13 W A.S.P. PROPOSED LOCATION AT TOTAL DEPTH: 2810 FT. FROM N LINE AND 337'S Fl'. FROM SECTION 23, T 8 N,, R 13 W A.S.P. E UNE ?,FCEtVED AnchoraG,~ ALASKA DIVISION DRILLING PROGNOSIS 7/13/90 WELL' C13A-23 LOCATION' PLATFORM 'C", LEG 4, CONDUCTOR 29 OBJECTIVE' HEMLOCK EVALUATION GEOLOGY SWEP~ ~NTEREST: 66.67% AFE NO: FIELD: MGS EST. ELEVATION: 105' (mean low low tide: 73') DRILLING CORES WELL CASING ELEC. MUD SIGNIFICANT DEPTH AND SURVEYS LOGGER FORMATIONS TVD MD CEMENT HOLE DEV. HOLE AND DIR. SIZE CONTROL MUD PROGRAM LIJ 0 o 0 0 0 24' Conductor 370' 13-3/8' Surface Casing GD 9-5/8' Protective Casing HC HZ' 7" Prod. Liner (TD) 1100' 8425 8425' 9205' 9905' 10039' 102' 9706' 97O6' 1O636' 11578' 11758' 17-1/2' 12-1/4" I' ~ 8-1/2' LI.I 0 X o ILl ~ Z'~ --J o LUo ~ o · ~ .~ o c~.~. O.~- "- LL "¢' 0'-- ...................... Seater. _~--t000~ ...... Grjd ._ Co rxec,.QQn_ _-:t~'L°18~ Net Magnetic Survey CorrectiOn=25.0°~5°00'7. Surface Location=Leg 4. Conductor 29 a 8 0 UPPER VERTICAL SECTION -'OR~E~~ ........ un[:) q?~'T~/n ' '-ii~ .... !TARGET ~2 _ .~ -_ ,- NE~IENT _-: .:.: :.::~_:--_:_:-E~~ ~ICAL SECTION' ............................................................ vSec Az ~0.O0 _ _ ........................... T - -~-~'~O ................................................. ~~D' .................. 1- _.L_ ======================== : ..... : ~_: :.:'7:;.:::: 0 CH^NGE TO LO~ER ¥SECPLAT ^T ~280JTVD_ -. · ..-- ...... :.. .......... :::::::::::::::::::::. ........... ........... VERTiCAL SECTION C1000':}: I I ' ............................................ ?/13/90 VERTICAL SECTION C1000'J MGS C33-26 SLOT RECOVERY PROGNOSIS STATUS' C33-26 was originally completed in July 1968 and converted to injection in July 1969. The well was shut in February 1982 and subsequent evidence of a 7" casing leak led to the well being plugged and abandoned in October 1982 (see Attachment I). OBJECTIVE: Remove 10-3/4" surface casing to a depth of 450' so that Conductor #29 on Leg 4 can be reused to drill Well C13/L-_23. ATTACHMENTS' I Present Status ....... . I I Proposed Status 1. Move rig over well. Check casing pressure. Remove dry hole tree cut away braidenhead. NU 20" riser and 10" diverter system. Function test diverter system. Give AOGCC 24 hours notice prior to installing diverter system. Rig up metal cuttings scalping shaker and cuttings chute off of the riser. . Drill out surface plug with a 9-7/8" bit and continue cleaning out hole to 650'. 3. Run a 10-3/4" casing scraper to 650'. 4. GIH with 10-3/4" bridge plug and set at 600'. . Displace Well with fresh water (well volume = 60 bbls). Add gel as required in anticipation of metal munching operations (Funnel viscosity : 150-200 and YP: 50). . Remove the 10-3/4" 40.5# J-55 BTC casing to at least 450' using the Tri-State metal muncher. Recommended BHA: Bullnose - Stab - DC - Stab -DC - Metal Muncher Mill - DC - Stab - DC - Jars - DCs. The 60' pilot assembly below the mill will help stabilize the BHA and will stay inside the 10-3/4" casing during connections to mitigate the possibility of sidetracking off of the casing stub. . With a 3-1/2" DP stinger inside the 10-3/4" casing stub at 600', spot a balanced cement plug across the 10-3/4" casing stub using densified Class "G" + 2% CaC12 + CFR-3 (16.7 ppg, 4.0 gal/sk, 1.02 cf/sk). Design for a TOC at 350' (assuming an open hole diameter of 20" to 410' and 17" below, this will require 280 sx of cement). This plug satisfies the requirements of 20 AAC 25.105(g)(3) and will also serve as a kickoff plug for C13A-23. Reverse out with seawater. Completely RRW/071290. . drain mud pits and clean out all metal cuttings from metal munching operations. Carefully clean the suctions and fluid ends of the mud pumps. After WOC 12 hours, clean out and drill cement to 375' using the kick off motor assembly. Use seawater as a drilling fluid. If the cement is hard at 375', prepare to kickoff Well 13A-23.. Approval-~~'~ Manager ~ Operati OhS ~ ~,-~7 RRW/071290. ATTACHMENT I MGS C33-26 PRESENT STATUS ~&A'd_ 10/82) 7/12/90' ESTIMATED TOC at 190' D~SPLACED 43fi3 'G" at 270' 24' CONDUCTOR at 370' TAGGED TOC at 1350' 7" CASING STUB at 1730' D~SPLACED 160 SX 'G' at 1830' TAGGED TOC at 8888' 26 SX 'G' SPOTTED on TOP of RETAINER BAKER K-1 RETAINER at 9045' 170 SX 'G' +0.1% R-5 +0.5% D- 19 SQUEEZED BELOW RETAINER RH-1 PACKER at 9877' RH-1 PACKER at 10013' RH-1 PACKER at 10123' 10-3/4" 40.5-~ J-55 BTC SURFACE CASING at 1604' CEMENTED W/ 1300 SX 'G" +10% GEL (12.8ppg) & 200 SX 'G' NEAT. AN ESTIMATED 160 BBLS of CEMENT RETURNS at SURFACE. TOC at 8200' 7' CASING CEMENTED W/ 900 SX 'G" +1% CFR-2 (15.8ppg) TOF at 9777' PERFORATIONS: 9395- 10340' BOT at 10162' (3-1/2" 9.3¢ J-55) PBTD at 10528' 7' PRODUCTION CASING at 10602' 0-8524' 26-,~' N-80 BTC nRp~-lnRnp' P.q~ N-RO RTC ATTACHMENT~ MGS C33-26 PROPOSED STATUS 7/12/90 KOP for C13A-23 at 375',~ 280-J: SX DENS~F~ED 'G' D~SPLACED ACROSS STUB BRIDGE PLUG at 600'+_. TAGGED TOO at 1350' 7' CASING STUB at 1730' DISPLACED 160 SX 'G' at 1830' TAGGED TOC at 8888' 26 SX 'G' SPOTTED ON TOP of RETAINER BAKER K-1 RETAINER at 9045' 170 SX 'G'+0.1% R-5 -I- 0.5% D- 19 SQUEEZED BELOW RETAINER RH-1 pACKER at 9877' RH- 1 PACKER at 10013' RH-1 PACKER at 10123' b~24' CONDUCTOR at 370' 10-3/4' CASING STUB at 450'-F 10-3/4' 40.5~ J-55 BTC SURFACE CASING at 1604' CEMENTED W/ 1300 SX 'G' -f- 10% GEL [12.8PPg~) & 200 SX 'G' NEAT. AN ESTIMATED 160 BBLS of CEMENT RETURNS at SURFACE. TOC at 8200' 7' CASING CEMENTED W/ 900 SX 'G' -I-1% CFR-2 (~ 15.8ppg~) TOF at 9777' PERFORATIONS: 9395 - 10340' BOT at 10162' (3-1/2' 9.3~ J-55;) PBTD at 10528' 7' PRODUCTION CASING at 10602' 0-8524' 26~ N-80 BTC 8524-10602' 29-~ N-80 BTC DRILLING PROGRAM MIDDLE GROUND SHOAL C13A-23 · · · · · Rig up. Drill out 24" casing shoe with 17-1/2" bit. Continue drilling to 375~. Kick off at 375~ and directionally drill to 13-3/8" casing point using 17-1/2" bit. Run and cement 13-3/8", 54.5#, K-55, BTC casing. Nipple up BOP stack. Test all connections, valves, and rams to 3,000 psi. Test annular preventer to 2,500 psi. Test all kelly, stand pipe, and emergency valves to 3,000 psi. Test casing to 1,500 psi. All tests performed in accordance with AOGCC regulations. Drill out 10~ and perform leak off test. Directionally drill 12-1/4" hole to 9-5/8" casing point. Run wireline logs. Run and cement 9-5/8", 43.5 and 47#, L-80, LTC casing. Nipple up BOP stack. Test all connections, valves, rams kelly, standpipe and emergency valves to 5,000 psi. Test annular preventer to 3,500 psi. Test casing to 3,000 psi. All tests performed in accordance with AOGCC regulations. 10. Drill out 10~ and perform leak off test. 11. Directionally drill 8-1/2" hole to TD. caliper log. Run wireline logs and casing 12. Run and cement 7", 26#, L-80 and 32#, P-110, LTC liner. 13. Proceed with cased hole completion prognosis. RRW/072490. RECOMMENDED MUD PROGRAM C13A-23 Interval: Mud Type: Recommended Properti es: Interval: Mud Type: Recommended Properties: Interval: Mud Type: Recommended Propert i es: 17-1/2" HOLE 0 to 1,102' Spud Mud (water and gel). Generic mud #2 * Weight = 8.5 to 9.0 ppg * Funnel Viscosity = 40 to 50 sec/qt * Plastic Viscosity = 5 to 10 cp * Yield Point : 10 to 20 lb/lO0 sq ft * Fluid Loss : no control * pH = 9.0 to 9.5 12-1/4" HOLE 1,102' to 9,706' Water and gel. Disperse only if required. Generic mud #2. * Weight = 8.8 to 9.5 ppg * Funnel Viscosity = 36 to 42 sec/qt * Plastic Viscosity: 5 t 12 cp * Yield Point : 10 to 15 lb/lO0 sq ft *API Fluid Loss : 20 cc * pH = 8.5 to 9.5 * MBT = 15 to 25 8-1/2" HOLE 9,706' to 11,758' Freshwater dispersed lignosulfonate mud with 1% KCl. * Weight: 9.3 to 9.8 ppg, or as required to combat waterflood pressure (11 ppg anticipated) * Salinity = 1% KCl * Funnel Viscosity - 40 to 45 sec/qt * Plastic Viscosity: 15-20 cp * Yield Point: 10-20 lb/lO0 sq ft *API Fluid Loss: 10 cc; 5 cc by HC * HTHP FL at 150°F: less than 20 cc; 10 cc by HC * pH: 9.5 t 10.5 * MBT: 15 to 25 RRW/072490. · · · · · · CASING AND CEMENT PROGRAM C13A-23 Run 13-3/8", 54.5#, K-55, BTC from 1,102' to surface. Casing design criteria are attached. Cement surface casing using 20% excess on gaged hole volume from TD to conductor shoe. Lead with 199 sx Class "G" + 10% gel + 2% CaC12 + defoamer and friction reducer as required (12.8 ppg, 11.5 gal/sk, 2.08 cf/sk) followed by 200 sx Class "G" + 2% CaC12 + defoamer and friction reducer as required (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). Perform top job within shoe of conductor. Run 9-5/8", 43.5 and 47#, L-80, LTC from 9,706' to surface. See attached casing design criteria. Cement to be 1000 ft above the shoe using 30% excess on caliper (preferably 4 arm caliper). Lead with an estimated 360 sx (based on a 15" hole) Class "G" + 4% gel + additives for rheologies (14.2 ppg, 7.6 gal/sk, 1.46 cf/sk, 2,000+ psi ultimate compressive strength) followed by 200 sx Class "G" + additives for rheologies (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). Run 7", 26 and 32#, L-80 and P-110, LTC from 11,758' to 300' above the 9-5/8" shoe. Extend the liner to cover any excessive casing wear in the 9-5/8". See attached casing design criteria. Cement liner with Class "G" + 1% KC1 + retarder + defoamer + fluid loss agent for WL less than 100 cc @ 150°F as required (15.5 ppg, 5.3 gal/sk, 1.19 cf/sk). An estimated 809 sx of cement will be required (based on 12-1/4" hole to the HC marker and 9-5/8" hole from the HC marker to TD). RRW/072490. C13A-23 CASING DESIGN Casing Design Criteria Frac Gradient Pressure Gradient Max Collapse Pressure Max Burst Pressure Projected Mud Weight 13-3/8" 9-5/8" 0.57 psi/ft 0.79 psi/ft 0.467 psi/ft 0.467 psi/ft 514 psi 3935 psi (Full evacuation) (Full evacuation) 1312 psi 3700 psi (1/3 BHP @ 9-5/8" csg pt) (Injection pressure) 9.6 ppg 9.6 ppg 1! 0.571 psi/ft 10000 psi (Frac pressure) 10000 ps i (Frac pressure) 11.0 ppg ACTUAL DESIGN CONDITION Size Depth Weight Grade/ (ppf) Coupling Buoyed Tension Collapse (lbs) (psi) Burst (psi) Casing Rating / Design Factors Tension Col 1 apse Burst (kips) (psi) (psi) 13-3/8" 9-5/8" !! 0- 1102 ' MD 0 - 1100 ' TVD 0- 4381 ' MD 0- 4000 ' TVD 4381 - 9706 ' MD 4000- 8425 ' TVD 9406- 10336 ' MD 8144- 8972 ' TVD 10336 - 11758 ' MD 8972 - 10039 ' TVD 54.5 K-55 BTC 43.5 L-80 LTC 47.0 L-80 LTC 26.0 L-80 LTC 32.0 P-110 LTC 51,448 327,022 151,003 11,329 (19,256) 514 1,312 1,868 3,700 3,935 3,700 5,122 3,700 10,000 10,000 853 / 10+ 825 / 2.52 905 / 5.99 519 / 10+ 897 / N/A 1131 / 2.20 2813 / 2.14 3699 / 1.98 6754 / 1.83 4807 / 1.22 6678 / 1.80 5435 / 1.06 7178 / 1.94 10847 / 1.08 12120 / 1.21 RRW/PROGCSG MISCELLANEOUS C13A-23 The maximum pressure gradient is expected to be .571 psi/ft. Maximum BHP is expected to be .571 x 10,039 : 5,732 psi. The shallowest depth at which abnormal waterflood pressures could be encountered is below the protective shoe. Maximum surface pressure is expected to be 2118 psi, assuming a full column of .360 psi/ft oil. The well will be drilled in compliance with the Alaska Oil & Gas Conservation Commission's regulations issued April 2, 1986. The proposed well path will pass in the vicinity of several active producers and injectors. In order to prevent possible intersections with these wells, collision cones of uncertainty will be calculated for each well based on the survey instruments used to survey each. The proposed wellpath will not intersect any of these collision cones. Should the actual wellpath intersect any of these collision cones, the affected well(s) will be shut in and bled down. Single shot gyro surveys will be taken while drilling the surface hole and MWD surveys will be used while drilling intermediate hole. As noted in the drawing of the diverter, both 10" mechanical valves will be kept in an open position until the preventer is closed. The mechanical valves will be wired full open and tagged with instructions concerning proper procedures for closing a valve in the event the preventer is closed. RRW/072490. ~--~'7-1/2" HOLE2000 PSI ~ACK FILL UP LINE MAIN DECK TOP OF KELLY BUSHING TOP OF DERRICK FLOOR '/ BOTTOM OF ROTARY BEAM ANNULAR PREVENTER 2000 PSI /-~o. ~ooo ~, ~.^~ IS CLOSED. 20" 2000 PSI RISER BOTH 10" MECHANICAL FULL-OPENING VALVES WILL BE IN AN OPEN POSITION. UPON CLOSING THE ANNULAR PREVENTER THE PROPER DIVERTER LINE IS SELECTEE 20" 2000 PSI FLANGE 7/26/89 WELLHEAD ROOM FLOOR - 1/4' HOLE 3000 PSi ,c'~"\CK ii ii i I iii I .;;,.)T-OL~ '.r :;OTA~Y BEAM ;-ILL JP LI~'JE _ ! "DRILL iii ii i · 'JIPPLrZ ~ LC,','; LI~E ANNUL AR PREVENI'ER 5000 ____...~13-518' 5000 PSI FLANGE L3LI'~D PAM %~00 P~I PIPE ;qAM ~000 P~l 2.- 1I~6' ~ILL LINE / / / ORILL SPOOL 5000 IISI RISER 13-~/~' &O00 IiSi FLANGE 3-~'8' r,;HOKE 13- 5/8' 13-5/8' 50('J0 PC TOP OF SUBBASE HEAD I b 3 -5/~' 3000 · '" !3'~/8' SO~ X ~3-5/'8" 3006 I~SI'",¥F' HOL~INo ' ; LANGE "r~xOF KELLY BUSHING 1 40' ' OF DERRICK FLOOR BOTTOM OF ROTARY BEAM J j-', DRILL NIPPLE FLOW LINE FILL UP LINE ANNULAR [./I PREVENTER PIPE RAM 5000 PSI ,._j ~P"I FLANGE 5000 TOP OF SUBBASE DRILL SPOOL MAIN DECK "~ncfloraga ~ ~ I1' 5000 PSI FLANGE 2 ~ 13'5/8' 3000 PSI FLANGE CASING~ HEAD ~ J WELLHEAD ROOM FLOOR ~ 9/10/87 13-3/8' SOW X 13-5/8' 3000 PSI 'WF' HOUSING N.T.S. NOTE: DIMENSIONS INCLUDE 1/'2' GAP BETWEEN FLANGES SHELL MINIMUM BOP STACK REQUIREMENTS Min. Min. No. Item I.D. Nominal 1 Flowline " ~" 2 Fill Up Line I I~ ' ' ~ brilling Nipple 4 Annular Preventer 5 Tw~ single or'one dual hydrualicall¥ operated rams 6 Drilling sPool' with 2" and 3" min. outlets 7 Gate Valve 3 1/8" B--- Gate Valve Power Operated 3-1/8" 9 Lin~ to choke manifold 3" · _ 10 Gate Valve 2-1/16" 1 i' Check Valve ' 2; 1/16" -- i 3 Easing Spool 14 Valves Gate 1-13/16" 15 Compound Pressure Gauge connector .. 16 Control Piug or valve 1-13/16" i7 kill iine~o rig mud pump manifold 2" i___8__2"X 2" X2"cros~ *NOTE: Additional specifications for Air/Gas Service are given in Shell Well Control Manual, Appendix 6.18. A rotating head shall be provided on Air/Gas Service OPTIONAL "i 2 Wear flange or bore protector r ~ ~ 19 Gate valve ................. 20 Line to roadside connection 2" 21 Rotating blowout preventer 22 Gate Valve power operated 6" .. DRAWING & CHECK LIST 104A SHELL CLASS 5M SURFACE INSTALLATIONS NORMAL AIR/GAS* FOR AIR/GAS DRILLING CONFIGURATION A .... ANNULAR PREVENTER BLIND RAM PIPE RAM Location optional SHELL MINIMUM AUXILIARY EQUIPMENT REQUIREMENTS Master control with Hvdril pressure regulatIng valve. 4 unit remote control Hydraulic BOP operating unit. ,Cee below for detail. · Kelly cocks [] Upper 1~3 Lower Pressure Rating St000 psi · Kelly saver sub with protector rubber. Inside BOP, surface type, for each size drill pipe. · Full opening ball valve for each size drill pipe in use. · Labelled crossover subs for each different connection in drill strin(~. OPTIONAL AUXILIARY EQUIPMENT - Circulating head for each size drill pipe in use with steel pipe and Chiksan joints to reach stand pipe connection. · Inside BOP - Drop or downhole type. Cup or plug type BOP tester with spare seals. SHELL MINIMUM HYDRAULIC OPERATING UNIT SPECIFICATIONS Accumulator volume - must deliver 1.5 times the voturne to make position change on all hydraut- ically operated units and retain 1200 psi (200 psi above precharge) without pumps. Pump capacity to obtain 200 psi above accumulator precharge pressure in two (2) minutes or less, while closing annular preventer and opening choke line valve. See Section 4.31. Power for pumps - 2 sources recluireci - Air-Electric or All Air (rig air plus separate air tank) - 2 pumps required. Lines from operating unit to BOP units 5,000 psi Minimum Yield [] Seamless steel lines .90" minimum I.D. [] Seamless steel lines with Chiksan joints. [] Hose per Section 4.32 Operatincj unit fluids' Hydraulic oil or soluble oil. All controls shall be clearly marked to show unit operated. Blind Ram control to have easily removed latch or ~luard. Sufficient bottled nitrogen or other back-up storage system to equal accumulator capacity, manifolded to by-pass accumulator and close BOP directly. Alarm, or visual indicator to show when accumulator is shut off from preventers. SHELL MINIMUM MUD SYSTEM REQUIREMENTS Pump stroke counters each pump. Deqasser. Pit volume recorder with alarm. Flow line monitor. OPTIONAL MUD SYSTEM EQUIPMENT Trip tank (with 6th man) Flow line gas separator. MISCELLANEOUS EQUIPMENT SPECIFICATIONS AND INSTALLATION INSTRUCTIONS 7. 1. All connections s..hall be welded, studded, flanged or Cameron clamp of comparable rating. 2. All flanges shall be APl 6B or 6BX and ring gaskets shall be APl steel RX or BX. Do not re-use BX rings. Always use new rings below lower most preventer when flanges are parted. 3. Drilling spools shal._..~l be forged or forged and wetded. Pipe spools not acceptable. 4. BOP stack shall be braced to subbase or suitable support by turnbuckled lines or rods. (No rigid connections. ) 5. All gate valves shall be equipped with handwheels. Rams should have manually operated screw locking extensIons (extended beyond subbase) ready for use. 6. For land rigs the master control station and operating unit shall be located at ground level a minimum of 50' from the well. The remote station is to be located near the driller's position. Inoperative condition of the remote unit is not to interfere with operation of the master control unit. For platform and barge rigs the master control station and operating unit may be on the rig floor with the remote station located so that is protected from the well area and accessible from a logical evacuation route. Hyctraulic lines may be high pressure hose provided they meet the require- ments in Section 4.32 in the Shell Well Control Manual. Housing and heating should be provided for accumulator, blowout preventers, choke manifold where conditions warrant. Contractor shall make no connection to casing head side outlets except by orders of Shell. One spare set of ram blocks for the drill pipe in use shall be kept on rigs. 10. Any misalignmen! of rig should be correctect to avoid undue wear of casing. 11, Four way valves shall be kept open or ctosed, not in neutral poslton. *Nor applicable to well servicing without drill pipe, PLATFORM 'C' SOLIDS CONTROL OPERATING MODE DRILLING UNWEIGHTED MUD DRILLING WEIGHTED MUD TRIPPING BUILD SLUG GATES CLOSED D, E, G D, E, G E,F, C,G C, D, F MUD FLOW ROUTING 1 -2-3-4-5 1 -2-3-4-5 4-5-2-3 1 -2-3-4 SOLIDS EQUIP. IN USE SS, 4" SS SS, 4' COMMENTS MAY WANT TO OPERATE 4' 4' TURNED OFF w/WEIGttTED MUD DERRICK FLO-LINE PlO ER BRANDT EGASSER BG-10 I t -- - -- I t Q ~,, TR AP SLUG PIT I I I I I I I I © --f I D~ I-C°l co NOTE' All equalizers [except from pit 1 to Legend ~ TOP EQUALIZATION ~ BOTTOM EQUALIZATION (:~ AGITATOR 2 are riser type and can be used lor eilher lop or bollom equalization. SHELL WESTERN E&P INC. MIDDLE GROUND SHOAL FIELD PLATFORM 'C' CHOKE MANIFOLD I 3' 5 KSI I_INES 2 Ct:lOSS 3' X 3' X 3' X 3' 5 KSI 3 CROSS 3' X 3' X 3' X 3' X 3' 5 KSI 4 3' 5 KSI GATE VALVE 5 AD,JUSTABLE MANUAL CHOKE - 3' 5 KSI 6 REMOTE OPERATED CHOKE - 2-9/16' '10KSI HYDRAULIC ADJUSTABLE 7. PRESS~JRE GAGE 8. 4" LINES 9. MUD/GAS SEPARATOR 10. 6" I_INE INLET~_~ MI.ID VENTED Ar CROW ALASKA,g, ,AND ' ( NSERVATION .... SUNDRY I' Io¥1CES AI D REPORT -};-,I WELLS 1. DRILLING WELL [] COMPLETED WELLX~ Injector Name of Operator Shell Oil Company 3. Address Wayne Simpson 601 H 5th Ave · .., 7r810, Anchorage, AK 99501 4. Location of Well Conductor 29, Leg 4, 42.6~' S. and 61.97' E. from the center of Leg I which is at 541.65' N and 1596.41 from the SE corner of Sec. 23, T8N, R12~'l, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 105' D. F. I 6 . Lease Designation and Serial No. ADL 18756 OTHER [] 7. Permit No. 68-54 8. APl Number 50- 1, 33-2r11 ?..~ 9. Unit or Lease Name MGS I ~10. Well Number C 33-26 11. Field and Pool MIDDLE GROUND SHOAL II p II u Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) {Submit in Duplicate) Perforate [] Alter Casing [] t Perforations E] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment , Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] , Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Prooosed or Completed Operations {Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work. for Abandonment see 20 AAC 25.105-170). See Attached. RECEIVED NOV 0 982 Alaska Oil & Gas Cons. Comrnis,~ion Anchorage d / ~" ,~ ~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~ ~ Title Production Administration The soace below for Commission use Date 10/22/82 Conditions of Approval. if any: By Order of Approved by COMMISSIONER the Commission [3ate ........... Form 10-403 Rev. 7-1 ~O Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate I' Kenai, Al< 10/17/82 10/20/82 I ' ' OCTOBER 19, 1982 P.O.H. WITH 7" CASING~ RECOVERED ~O.~.O.!,NT:S_:.&;_SZsCUTOFF.~,. . RIG UP B-O C~NIERS, MiX ,~D PU~ ~8 .P,l. C~SS G NEAT CEMENT, H]X N/SEA g~ATER. DISPLACE ~/55 ~.3 SEA WATER, ~EI-:CEMENT::PLUG~..IO0~ ~NSlI)E:.-?'~.TCUTOFF ACROSS 125' .OF 8 3/4" OPEN HOLE AND..:2.0Q?:.U~:.INSIDE'.'..~IO:3]~.,", . PLUG) C,I.P. @ 1010 HRS, W,O.C, RIG UP DIALOG TO RUN 10 3/4" CASING CALIPER LOG. CALIPER LOG SHOWED 85% OF CASING WALL TH'ICKNESS REMAINING, R.I.FI. 14/3.~" DRILL PIPE AND FEEL FOR EMENT @ 2200 HRS FOUND ~O~@~ri350:~.R.F. MEASUREMENTS HARD CEMENT. P..O.H. LAYING DO~'N I~IPE, R.I.H.' TD~2/O"~HI~X"~AND:'-PUMP~3:~'FT~EASS~ A.P.I. NEAT CEMENT SEA WATER MIX, DISPLACE W/6 F-F,3 SEA WATER, C.I.P, @ 12 HIDC~JGHT, SERVICE PLtqPS & RIG FOR SHUT DOWN. BREAK DOWN 4 STANDS IN MOUSE HOLE AND LAY DOk~N 3~" DRILL PIPE. WAIT ON CEMENT, SERVICE RIG AND PUMPS FOR SHUT DOWN. ~Y D<TgN KELLEY MOUSE HOLE AND RAT HOLE, NIPPLE DOWN B.O.P- STACK AND RISER. SET CAMERON .X-NAS TREE BACK ON WELL HEAD, l:O0 P.H~ RELEASED 1 DRiLLING.CREW AND SENT TO PLATFORM "A". MOTH BALLED' RIG. RELEASED 2ND CREW @ 4:00 P,M. ~IG'RELEASED~FROM C33-26 @ 4:00 P,M. REEEI-VED NOV 0 982 A~aska Oil & Gas 1'41DFJL E P~.ROUItD SI-IO,qL · Kenai, /~K 10/17/82 10/20/82-_ . St'atus' Tubing cut at 9415'. Well' determined uneconomical due to casing damage . and fish :-in hole. Proposal' Plug and abandon well. OCTOBER 17, 19821 R.I.H.'~/ITH 6" BIT AND 7" CASING SCRAPER TO 9350'. CIRCULAIE WII}t SALT WATER, P.O.H., R.I.H. W//j!:~BAK£R /qODELt-K-I''CENENT REIA]NER AND~::SE~..17@'::.9045'..?' PUMP IO0.-FT.3 SALT W~IER'O 1200 P.S,I. FOR BREAK OC~N @ 6 H.3/min,~ STRING OUT OF RETAINER, PUMP 50 FT.3 FRESH , H2~_ HIX AND PUMPc194"FT¥~.:,'~3EMEN~, FOLLOW W/5D H.3 FRESH H20 & 50 FT.3 SALT H20 STING INTO RETAINER PUNP~BL-Ff~3~AIzT~HI~O.:zl..O.:P. Lff?.:¢ELdENT PLACE, FINAL:~?R.E$SU~_E_.~J..~O.O.;.:,,.~.,._S:!~ PULL OUT OF RETAINER, SPOT 145' PLUG ABOVE RETAJNER (30 FT..3 CEMENT) PULL lO STANDS PIPE CLEAN. CEMENT IN PLACE @ 2200 HRS. CLEAN /OdD PIIS SERVICE AND CLEAN' RIG. NOTE: ASKED FOR AND RECEIVED VERBAL EXEMPTION FROM OIL AND GAS C.ONSERVA)ION COfqFI]SSION ON MUDDING UP AFTER PLUGS WERE SET. t OCTOP, ER 18, :t 98! WAIT ON CE~, C ~I.SAN I¥i'dD P1TS~ SE1A,"JL't] AND GLEt~ R16. FOR ®~T e 1000 ERS.CF(lIND .TOP~_@Z88_85J (12i Hi(H) P.O.H. lAYING LO~ D.P. ,1<:.RK ON 'TONC~ ANI). CA~a~(ECR tlNIT) FO~,FD FIE.E.D i,~]t,/DTING IN ROTARY . · .~,~TOR BtrRt~] OUT. FlHI~ ~ OF HOLE ~'/I-~.'D_RAULIC TO~'.4'C~ RL~ I'IART TOOL AND Ptq~t, CAqP~RON JtOLL W~-V]L HANGER SFAh ASS~,IBLY. /UG UP DIklJDG. SHOOT 7" - 26# CAS] ~;G[8.:1730.!-7 R:. F RECEIVED : ............ --' ~-,ao, -~/~ orage ~HECK LIST FOE NEW WELL PEPS!ITS 'iT_WE APPROVE DATE (2) L0,~, ~/P~ ~ (2~uhru 8) (%~.:,~ r~ ~) lo. (10 ~d 13) 12.. 13. (14 :~ Z2) (23 thr~ 28) (6) Geolo - Enzinee ing- ~ DWJ-~J~C$ ~i:~ SEW / -, rev: 01/30/89 6.011. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Is the permit fee at=ached .......................................... YES NO - ,, 2. !$ well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells ........ ~ ........... 5. Is sufficient undedicated acreage available in this pool ............ 6. is well to be deviated and is we!!bore plat included ................ 7. is operator the only affected par~y ......... i ....................... 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ is a conservation order needed ...................................... Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... Does the we!! have a unique name and number ......................... !s cdnductor string provided ........................................ Will surface casing protect all zones reasonably expected to sez~e as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement ~ie in surface and intermediate or production strings ... Will cement cover all kno%m productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from a~ ez~sting we!lbore ............. Is old we!!bore abandonment procedure included on 10-403 ............ Is adequate wei!bore separation proposed' is a diver=er system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrmm~ and descriptions of diveruar and BOPE attached. Does BOPE have sufficient pressure rating - Test to 5o~-o~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .... ~ .............. Is the presence of ~2S gas probable ............................. ~... axplorator7 and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented ,, Additional requirements ............................................. Additional Remarks: INITIAL GEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE /-o.'/ V. o ,=,('7' , Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No special'effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LIS .000 1024 CN WN FN COUN STAT : SHELL WESTERN E&P, INC. : C13A-23 : MIDDLE GROUND SHOAL : KENAI : ALASKA LIS COMMENT RECORD (s): RUN 1 MAIN PASS. * FORMAT RECORD (TYPE# 64) RECEIVED AUG 0 ~ 1993 Ala$~ Oil & Gas Cons. Commission Anchorage ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 AC AC 68 1 US/F 2 CAL AC 68 1 IN 3 CHT AC 68 1 LB 4 SPD AC 68 1 F/MN 5 TTEN AC 68 1 LB 6 GR DIFL 68 1 GAPI 7 CILD DIFL 68 1 MMHO 8 RFOC DIFL 68 1 OHMM 9 RILD DIFL 68 1 OHMM 10 RILM DIFL 68 1 OHMM 11 SP DIFL 68 1 MV 4 48 852 89 1 4 94 885 22 5 4 95 558 30 1 4 61 094 30 1 4 95 558 30 1 4 67 456 14 5 4 34 704 23 6 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 * DATA RECORD (TYPE# 0 ) 1014 BYTES * 44 Total Data Records: 1637 Tape File Start Depth = 9847.000000 Tape File End Depth = 1255.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 412429 datums Tape Subfile: 2 1642 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** .000 1024 CN WN FN COUN STAT : SHELL WESTERN E&P, INC. : C13A-23 : MIDDLE GROUND SHOAL : KENAI : ALASKA LIS COMMENT RECORD (s): RUN 2 MAIN PASS. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 31 Curves: Name Tool Code Samples Units 1 AC AC 68 1 US/F 2 ACQ AC 68 1 3 CAL AC 68 1 IN 4 CHT AC 68 1 LB 5 SPD AC 68 1 F/MN 6 TTEN AC 68 1 LB 7 CILD DIFL 68 1 MMHO 8 RFOC DIFL 68 1 OHMM 9 RILD DIFL 68 1 OHMM 10 RILM DIFL 68 1 OHMM 11 SP DIFL 68 1 MV 12 GR DIFL 68 1 GAPI 13 CAL CDL 68 1 IN 14 CORR CDL 68 1 G/C3 15 DEN CDL 68 1 G/C3 16 LSD CDL 68 1 CPS 17 SSD CDL 68 1 CPS 18 CN 2418 68 1 PU-L 19 CNC 2418 68 1 PU-S 20 LSN 2418 68 1 CPS 21 SSN 2418 68 1 CPS 22 CHT 2418 68 1 LB 23 SPD 2418 68 1 F/MN 24 TTEN 2418 68 1 LB 25 GR SL 68 1 GAPI 26 K SL 68 1 % 27 KTH SL 68 1 GAPI 28 TH SL 68 1 PPM 29 U SL 68 1 PPM 30 RLML ML 68 1 OHMM 31 RNML ML 68 1 OHMM API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 48 852 89 1 4 4 81 285 47 0 4 4 94 885 22 5 4 4 81 285 47 0 4 4 65 096 04 5 4 4 95 558 30 1 4 4 34 704 23 6 4 4 27 515 24 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 67 456 14 5 4 4 87 374 67 0 4 4 34 168 75 6 4 4 59 047 24 5 4 4 03 752 11 6 4 4 03 096 75 6 4 4 31 149 96 6 4 4 86 720 65 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 86 720 65 6 4 4 65 866 87 0 4 4 31 402 87 0 4 4 61 486 11 5 4 4 37 159 39 6 4 4 45 226 21 6 4 4 95 248 10 1 4 4 26 320 10 1 4 4 02 658 84 0 4 4 71 586 84 0 * DATA RECORD (TYPE# 0) Total Data Records: 1459 902 BYTES * 124 Tape File Start Depth = 11742.000000 Tape File End Depth = 9190.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 326689 datums Tape Subfile: 3 Minimum record length: Maximum record length: 1465 records... 62 bytes 902 bytes Tape Subfile 4 is type: LIS **** FILE HEADER **** .001 1024 CN WN FN COUN STAT : SHELL WESTERN E&P, INC. : C13A-23 : MIDDLE GROUND SHOAL : KENAI : ALASKA LIS COMMENT RECORD (s) : RUN 1 REPEAT PASS. * FORMAT RECORD (TYPE# 64) Tape Subfile 5 is type: LIS **** FILE HEADER **** .002 1024 CN WN FN COUN STAT : SHELL WESTERN E&P, INC. : C13A-23 : MIDDLE GROUND SHOAL : KENAI : ALASKA LIS COMMENT RECORD (s): RUN 2 REPEAT PASS. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 31 Curves: Name Tool Code Samples Units 1 AC AC 68 1 US/F 2 ACQ AC 68 1 3 CAL AC 68 1 IN 4 CHT AC 68 1 LB 5 SPD AC 68 1 F/MN 6 TTEN AC 68 1 LB 7 CILD DIFL 68 1 MMHO 8 RFOC DIFL 68 1 OHMM 9 RILD DIFL 68 1 OHMM 10 RILM DIFL 68 1 OHMM 11 SP DIFL 68 1 MV 12 GR DIFL 68 1 GAPI 13 CAL CDL 68 1 IN 14 CORR CDL 68 1 G/C3 15 DEN CDL 68 1 G/C3 16 LSD CDL 68 1 CPS 17 SSD CDL 68 1 CPS 18 CN 2418 68 1 PU-L 19 CNC 2418 68 1 PU-S 20 LSN 2418 68 1 CPS 21 SSN 2418 68 1 CPS 22 CHT 2418 68 1 LB 23 SPD 2418 68 1 F/MN 24 TTEN 2418 68 1 LB 25 GR SL 68 1 GAPI 26 K SL 68 1 % 27 KTH SL 68 1 GAPI 28 TH SL 68 1 PPM 29 U SL 68 1 PPM 30 RLML ML 68 1 OHMM 31 RNML ML 68 1 OHMM API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 48 852 89 1 4 81 285 47 0 4 94 885 22 5 4 81 285 47 0 4 65 096 04 5 4 95 558 30 1 4 34 704 23 6 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 67 456 14 5 4 87 374 67 0 4 34 168 75 6 4 59 047 24 5 4 03 752 11 6 4 03 096 75 6 4 31 149 96 6 4 86 720 65 6 27 466 87 5 28 122 23 5 86 720 65 6 65 866 87 0 31 402 87 0 61 486 11 5 39 6 21 6 10 1 10 1 84 0 84 0 37 159 45 226 95 248 26 320 02 658 71 586 124 * DATA RECORD (TYPE# 0) Total Data Records: 1103 902 BYTES * Tape File Start Depth = 11650.000000 Tape File End Depth = 9721.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 573634 datums Tape Subfile: 5 1109 records... Minimum record length: 62 bytes Maximum record length: 902 bytes Tape Subfile 6 is type: LIS **** TAPE TRAILER **** 93/ 7/28 01 **** REEL TRAILER **** 93/ 7/28 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 28 JLY 93 12:35p Elapsed execution time = 1 minute , 8.3 seconds. SYSTEM RETURN CODE = 0